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196-202
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250613 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN-17A 50733203110100 213049 4/14/2025 AK E-LINE GPT T40549 AN-17A 50733203110100 213049 4/16/2025 AK E-LINE Perf T40549 BRU 244-27 50283201850000 222038 5/15/2025 AK E-LINE Perf T40550 IRU 241-01 50283201840000 221076 5/16/2025 AK E-LINE Perf T40551 KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP T40552 KU 13-06A 50133207160000 223112 5/9/2025 AK E-LINE Perf T40552 KU 33-08 50133207180000 224008 5/30/2025 AK E-LINE Perf T40553 MPU K-33 50029227290000 196202 5/2/2025 AK E-LINE Caliper T40554 Aurora S-100A 50029229620100 224083 5/8/2025 BAKER MRPM Borax #2 T40555 PBU 06-12C 50029204560300 225022 5/15/2025 BAKER MRPM T40556 PBU B-30B 50029215420200 225009 4/9/2025 BAKER MRPM T40557 PBU D-03B 50029200570300 225008 5/2/2025 BAKER MRPM T40558 PBU H-29B 50029218130200 225005 5/7/2025 BAKER MRPM T40559 END 1-25A 50029217220100 197075 5/4/2025 HALLIBURTON MFC40 T40560 END 3-03 50029223060000 192121 5/18/2025 HALLIBURTON PPROF T40561 NS-33A 50029233250100 208189 5/13/2025 HALLIBURTON MFC24 T40562 PBU D-03B 50029200570300 225008 5/2/2025 HALLIBURTON RBT T40558 PBU H-29B 50029218130200 225005 5/7/2025 HALLIBURTON RBT T40559 PBU L-108 50029230900000 202109 5/16/2025 HALLIBURTON IPROF T40563 Please include current contact information if different from above. MPU K-33 50029227290000 196202 5/2/2025 AK E-LINE Caliper Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.17 11:38:14 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to ESP 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,543'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9,310' 11,483' 9,251' 1,029 N/A KUPARUK RIVER OIL & SAG RIVER OIL N/A Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT K-33 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 2/25/2025 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0375132 & ADL0375133 196-202 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22729-00-00 Hilcorp Alaska LLC C.O. 432E & 423 Length Size Proposed Pools: 112' 112' 9.2 / 13 CR-85 / VAM TVD Burst 9,703' MILNE POINT 8,993 MD / 6,786 TVD & 9,594 MD / 7,381 TVD and N/A MD N/A 5,750psi 7,240psi 4,948' 9,593' 6,666' 11,526' (2) HES TNT Packers and N/A 112' 20" 9-5/8" 7" 6,666' 11,526' Todd Sidoti todd.sidoti@hilcorp.com 777-8443 Perforation Depth MD (ft): See Schematic See Schematic 3-1/2" 4-1/2" 12.6 / 13 CR-85 / VAM 8,956' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-090 By Gavin Gluyas at 9:51 am, Feb 20, 2025 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.02.20 07:14:45 - 09'00' Taylor Wellman (2143) DSR-2/20/28 * BOPE test to 2000 psi. A.Dewhurst 20FEB25 10-404 MGR12MAR25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.13 14:05:52 -08'00'03/13/25 RBDMS JSB 031825 RWO – ESP Install Well: MPU K-33 Date:31 Jan 2025 īôÍŜôϟIJĺťôϦϟèēÍIJČôŜϟťĺϟŕŕŘĺŽôîϟŪIJîŘƅϳϟ͙͗͘Ϸ͚͗͜ϟÍŘôϟĖIJϙŘôîϧ ®ôīīϙbÍıôϡ aXϱ͒͒IϙbŪıæôŘϡ ͔͏ϱ͏͑͘ϱ͖͑͑͑͘ϱ͏͏ϱ͏͏ ŪŘŘôIJťϙťÍťŪŜϡ I V ŘĺîŪèôŘ Íîϡ XϱÍî (ŜťĖıÍťôîϙťÍŘťϙ"Íťôϡ ͓͐ϙ>ôæϙ͑͏͔͑ĖČϡ ͐ ôČϟϙŕŕŘĺŽÍī ôŗЍîϦ ´ôŜ "Íťô ôČϟϙŕŕŘĺŽÍī ôèЍŽîϡ ͕͑ϙôŕϙ͓͑ ŪIJîŘƅϭϙ͓͒͑ϱ͔͖͑ ôČŪīÍťĺŘƅϙ ĺIJťÍèťϡ ĺıϙ>ĺŪťŜ ôŘıĖťϙťĺϙ"ŘĖīīϙbŪıæôŘϡ ͕͐͘ϱ͑͏͑ >ĖŘŜťϙ Íīīϙ(IJČĖIJôôŘϡ (ŘĖħϙϟϙbôīŜĺIJ ϼ͘͏͖Ͻϙ͔͕͓ϳ ͔͖͖͑ϙϼiϽ ϼ͘͏͖Ͻϙ͘͏͒ϳ ͖͓͏͖ϙϼ Ͻ ôèĺIJîϙ Íīīϙ(IJČĖIJôôŘϡ ÍƅīĺŘϙ®ôīīıÍIJ ϼ͘͏͖Ͻϙ͖͖͖ϳ ͓͓͗͘ϙϼiϽ ϼ͘͏͖Ͻϙ͓͖͘ϳ ͔͒͒͘ϙϼ Ͻ ŪŘŘôIJťϙĺťťĺıϙFĺīôϙŘôŜŜŪŘôϡ ͐͑͘͘ϙŕŜĖϙЬϙ͖͏͗͏Ѝϙ«"ϙ ͏͐ϯ͒͏ϯ͑͏͔͑ϙ(a®ϙи ͔ϟ͓ϙ@( aϡ ͓͐͑͗ϙŕŜĖ @ÍŜϙ ĺīŪıIJϙ@ŘÍîĖôIJťϙϼ͏ϟ͐ϙŕŜĖϯċťϽ aÍƄϙIIJèīĖIJÍťĖĺIJϙϼÍĖīϙ®ôīīϽϡϙ ϙϙϙϙϙ͔͗ϟ͔ϙîôČϙЬϙ͓͕͗͐Ѝ aĖIJϙôŜťŘĖèťĖĺIJϡ ͑ϟ͖͔͏ЋϙЬϙ͕͐͘͘Ѝϙϼ͒ϟ͔Ћϙ³bϽ ŘĖôċϙ®ôīīϙŪııÍŘƅϡ aϙXϱ͒͒ϙſÍŜϙîŘĖīīôîϙÍIJîϙċŘÍèЍîϙĖIJϙVÍIJŪÍŘƅϙ͖͐͘͘ϙÍŜϙÍϙÍČϙŕŘĺîŪèôŘϟϙIťϙĖŜϙèŪŘŘôIJťīƅϙèĺIJċĖČŪŘôîϙÍŜϙÍϙ ϙĤôť ŕŪıŕϙÍIJîϙŜĖIJèôϙťēôŘôϙĖŜϙIJĺϙŕĺſôŘϙċīŪĖîϙÍŽÍĖīÍæīôϙÍťϙXϱŕÍîϙſôϙſĖīīϙèĺIJŽôŘťϙťēôϙſôīīϙťĺϙ(ϙÍIJîϙŘôťŪŘIJϙťĺ ŕŘĺîŪèťĖĺIJϟ bĺťôŜϙôČÍŘîĖIJČϙ®ôīīæĺŘôϙ ĺIJîĖťĖĺIJ x ͒͏ϙVÍIJϙ͔͑ϙϳϙīĖèħīĖIJôϙŕôŘċĺŘıôîϙFϙŜŪŘŽôƅ x ͑͗ϙVÍIJϙ͔͑ϙϳϙīĖèħīĖIJôϙŘÍIJϙ͒ϟ͗͏ϱĖIJϙČÍŪČôϙŘĖIJČϙÍIJîϙŕŪīīôîϙ͒ЋϙV x aIϱƄIϙťĺϙ͔͒͏͏ϙŕŜĖϙŕÍŜŜôîϙĺIJϙ͐ϯ͐͗ϯ͑͏͕͐ϟ iæĤôèťĖŽôϡ Ūīīϙ͓ϱ͐ϯ͑ЋϙŪŕŕôŘϙèĺıŕīôťĖĺIJϠϙĖIJŜťÍīīϙÍ ͓ϱΫЋϙ(ϙèĺıŕīôťĖĺIJϙÍIJîϙŘôťŪŘIJϙſôīīϙťĺϙŕŘĺîŪèťĖĺIJϟ ŘôϱĖČϙŘĺèôîŪŘôϙϼbĺϙŜŪIJîŘƅϙŘôŗŪĖŘôîϽϡ īĖèħīĖIJôϙЭϙ>ŪīīæĺŘô ͐ϟ aIϙ[ϙÍIJîϙċŪīīæĺŘôϠϙŕŘôŜŜŪŘôϙťôŜťϙīŪæŘĖèÍťĺŘϙťĺϙ͔͑͏ϙŕŜĖϙīĺſϙϯϙ͑͏͏͏ϙŕŜĖϙēĖČēϟ ͑ϟ IFϙÍIJîϙŜôťϙŕīŪČϙĖIJϙ͓ϟ͔Ћϙ³ϙIJĖŕŕīôϙЬϙ͗͑͗͘ЍϟϙiiFϟ ͒ϟ ôŘċĺŘıϙ aIϱƄIϙťĺϙ͔͑͏͏ϙŕŜĖϟ ͓ϟ IFϙÍIJîϙŕŪīīϙŕīŪČϟ ͔ϟ iiFϙÍIJîϙ"aiϙ[ϟ (īĖIJôϙЭϙ>ŪīīæĺŘô ͕ϟ īôÍŘϙÍIJîϙīôŽôīϙŕÍîϙÍŘôÍϙĖIJϙċŘĺIJťϙĺċϙſôīīϟϙŕĺťϙŘĖČϙıÍťŜϙÍIJîϙèĺIJťÍĖIJıôIJťϟ ͖ϟ "ϙſôīīϙēĺŪŜôϙÍIJîϙċīĺſīĖIJôŜϟϙϙ īôÍŘϙÍIJîϙīôŽôīϙÍŘôÍϙÍŘĺŪIJîϙſôīīϟ ͗ϟ ϙŘôŽôŘŜôϙĺŪťϙŜħĖîϙÍIJîϙ͔͏͏ϙææīϙŘôťŪŘIJŜϙťÍIJħϟ ͘ϟ aIϙôīĖIJôϙÍIJîϙŕŘôŜŜŪŘôϙťôŜťϙ (ϙťĺϙ͔͑͏ϙŕŜĖϙīĺſϙϯϙ͑͏͏͏ϙŕŜĖϙēĖČēϟ ͐͏ϟ IFϙſĖťēϙıôèēÍIJĖèÍīϙťŪæĖIJČϙèŪťťôŘϟ RWO – ESP Install Well: MPU K-33 Date:31 Jan 2025 ͐͐ϟ ĺŘŘôīÍťôϙťĺϙťŪæĖIJČϙťÍīīƅϙÍIJîϙèŪťϙæôīĺſϙťĺŕϙèĺIJIJôèťĖĺIJϙĺIJϙťēôϙ͒ϟ͔ЋϙŜēĺŘťϙĤĺĖIJťϙÍťϙ͕͗͘͏ЍϟϙiiF ÍIJîϙ"aiϙôīĖIJôϟ ͐͑ϟ ĖŘèŪīÍťôϙÍťϙīôÍŜťϙĺIJôϙſôīīæĺŘôϙŽĺīŪıôϙſĖťēϙŕŘĺîŪèôîϙſÍťôŘϙîĺſIJϙťŪæĖIJČϠϙťÍħĖIJČϙŘôťŪŘIJŜϙŪŕ èÍŜĖIJČϙťĺϙ͔͏͏ϙææīϙŘôťŪŘIJŜϙťÍIJħϟ ͐͒ϟ ĺIJċĖŘıϙſôīīϙĖŜϙîôÍîϟϙ ĺIJťÍèťϙťēôϙĺŕôŘÍťĖĺIJŜϙôIJČĖIJôôŘϙĖċϙċŘôôƏôϙŕŘĺťôèťĖĺIJϙĖŜϙIJôôîôî îôŕôIJîĖIJČϙĺIJϙϙÍŘŘĖŽÍīϟ ͓͐ϟ "ϙċŪīīæĺŘôϙŕŪıŕôŘŜϙÍIJîϙŘôŽôŘŜôϙĺŪťϙŜħĖîϟ ͔͐ϟ ϙèŘÍIJôϟϙôťϙ«ϟϙb"ϙťŘôôϙÍIJîϙťŪæĖIJČϙēôÍîϙÍîÍŕťôŘϟϙbϙi(ϟ ͕͐ϟ bϙi(ϙēĺŪŜôϟϙŕĺťϙıŪîϙæĺÍťϟ ŘĖôċϙ®iϙŘĺèôîŪŘôϙϼŪIJîŘƅϙŕŕŘĺŽÍīϙôŗŪĖŘôîϽϡ ͖͐ϟ aIϙFĖīèĺŘŕϙϙϭ͐ϙ®iϙĖČϠϙÍIJèĖīīÍŘƅϙôŗŪĖŕıôIJťϠϙÍIJîϙīĖIJôŜϟ ͐͗ϟ ēôèħϙċĺŘϙŕŘôŜŜŪŘôϙÍIJîϙĖċϙ͏ϙŕŜĖϙŜôťϙ ϙŕīŪČϟϙϙIċϙIJôôîôîϠϙæīôôîϙĺċċϙÍIJƅϙŘôŜĖîŪÍīϙŕŘôŜŜŪŘôϙĺċċ ťŪæĖIJČϙÍIJîϙèÍŜĖIJČϟϙϙIċϙIJôôîôîϠϙħĖīīϙſôīīϙſϯϙŕŘĺîŪèôîϙſÍťôŘϙŕŘĖĺŘϙťĺϙŜôťťĖIJČϙ ϟ ͐͘ϟ ôŜťϙi(ϙťĺϙ͔͑͏ϙŕŜĖϙ[ĺſϯϙ͑Ϡ͏͏͏ϙŕŜĖϙFĖČēϠϙÍIJIJŪīÍŘϙťĺϙ͔͑͏ϙŕŜĖϙ[ĺſϯϙ͑Ϡ͏͏͏ϙŕŜĖϙFĖČēϙϼēĺīîϙôÍèē ŘÍıϯŽÍīŽôϙÍIJîϙťôŜťϙċĺŘϙ͔ϱıĖIJϽϟϙôèĺŘîϙÍèèŪıŪīÍťĺŘϙŕŘôϱèēÍŘČôϙŕŘôŜŜŪŘôŜϙÍIJîϙèēÍŘťϙťôŜťŜϟ Íϟ ôŘċĺŘıϙôŜťϙŕôŘϙϙ͐ϙiϙôŜťϙŘĺèôîŪŘô æϟ bĺťĖċƅϙi@ ϙ͓͑ϙēĺŪŘŜϙĖIJϙÍîŽÍIJèôϙĺċϙiϙťôŜťϟ èϟ ĺIJċĖŘıϙťôŜťϙŕŘôŜŜŪŘôŜϙŕôŘϙťēôϙŪIJîŘƅϙèĺIJîĖťĖĺIJŜϙĺċϙÍŕŕŘĺŽÍīϟ îϟ ôŜťϙ«ϙŘÍıŜϙĺIJ ͒ϱ͐ϯ͑ЋϙÍIJîϙ͓ϱ͐ϯ͑ЋϙťôŜťϙĤĺĖIJťϟ ôϟ ŪæıĖťϙťĺϙi@ ϙèĺıŕīôťôîϙ͐͏ϱ͓͓͑ϙċĺŘıϙſĖťēĖIJϙ͔ϙîÍƅŜϙĺċϙi(ϙťôŜťϟ ͑͏ϟ Ūīīϙ ϙŕīŪČϟϙīôôîϙÍIJƅϙŕŘôŜŜŪŘôϙĺċċϙťŪæĖIJČϙťĺϙťēôϙŘôťŪŘIJŜϙťÍIJħϟϙXĖīīϙſôīīϙſĖťēϙŕŘĺîŪèôîϙſÍťôŘ ÍŜϙIJôôîôîϟϙŪīīϙ«ϟ ͑͐ϟ aϙīÍIJîĖIJČϙĤĺĖIJťϙĺŘϙŜŕôÍŘϠϙϙÍIJîϙŘôèĺŽôŘϙťŪæĖIJČϙēÍIJČôŘϟ Íϟ ôèĺŘîôîϙϙſôĖČēťϙſÍŜϙ͓͐͑ħϙÍIJîϙiϙſÍŜϙ͐͏͖ħϟ ͑͑ϟ iiFϙÍIJîϙīÍƅϙîĺſIJϙťēôϙ͓ϱ͐ϯ͑ЋϙťŪæĖIJČϟ Íϟ ͓ϱ͐ϯ͑ЋϙĖŜϙèēŘĺıôϙÍIJîϙſĖīīϙŘôŗŪĖŘôϙťēôϙÍŜŜĺèĖÍťôîϙēÍIJîīĖIJČϙôŗŪĖŕıôIJťϟ æϟ ÍŽôϙÍīīϙèēŘĺıôϙĤĺĖIJťŜϙÍIJîϙĤôſôīŘƅϙċĺŘϙĖIJŜŕôèťĖĺIJϙÍIJîϙŘôϱŪŜôϟ ͑͒ϟ aϙÍIJîϙIFϙſĖťēϙ͖ЋϙèÍŜĖIJČϙŜèŘÍŕôŘϙÍŜŜôıæīƅϟ ͓͑ϟ èŘÍŕôϙÍIJîϙèīôÍIJϙĺŪťϙťĺϙ͗͘͏͏ЍϟϙiiFϟ ͔͑ϟ ϙŜŕĺĺīôŘϙťĺϙĖIJŜťÍīīϙ(ϙèÍæīôϟ ͕͑ϟ ϙIJôſ ͓ϱΫЋϙ͐͒ Řϙ(ϙèĺıŕīôťĖĺIJϙÍIJîϙŘŪIJϙťĺϙ͗͗͑͏Ѝϡ (ϙŜŜôıæīƅ ϳ ôIJťŘÍīĖƏôŘϙÍťϙ͗͗͑͏Ѝ ŪŕϙVĺĖIJťϠ ͓ϱΫЋϙ͐͒ Ř ͐ϙVĺĖIJťϙŪæĖIJČϠ ͓ϱΫЋϙ͐͒ Ř ͓ϱΫЋϙ͘ ŘϙĺŘϙ͐͒ Řϙ³bϱIJĖŕŕīôϙŕŘĺċĖīôϙϼ͒ϟ͗͐͒ϱĖIJϯ͒ϟ͖͔͑ϱĖIJϽ ŪŕϙVĺĖIJťϠ ͓ϱΫЋϙ͘ Ř ͓ϱΫЋ [͗͏@[aϙÍťϙѹ͖͗͏͏Ѝ ϳ "Ūııƅϙ@[«ϙIIJŜťÍīīôî ŪŕϙVĺĖIJťϠ ͓ϱΫЋ ͘ Ř VĺĖIJťŜŪæĖIJČϠ ͓ϱΫЋϙ͐͒ Ř RWO – ESP Install Well: MPU K-33 Date:31 Jan 2025 ŪŕϙVĺĖIJťϠ ͓ϱΫЋϙ͘ Ř ͓ϱΫЋϙ[͗͏@[aϙÍťϙѹϙ͑͏͏ЍϙiŘĖċĖèôϙ@[«ϙIIJŜťÍīīôî ŪŕϙVĺĖIJťϠ ͓ϱΫЋϙ͘ Ř VĺĖIJťŜŪæĖIJČϠ ͓ϱΫЋϙ͐͒ Ř "ŕÍèôϙiŪťϙŪŕŜϠ ͓ϱΫЋϙ͐͒ Ř ͐ϙVĺĖIJťϙŪæĖIJČϠ ͓ϱΫЋϙ͐͒ Ř ͖͑ϟ ŕÍèôϙĺŪťϠϙťôŘıĖIJÍťôϙ(ϙèÍæīôϙÍIJîϙīÍIJîϙēÍIJČôŘϟ ͑͗ϟ ôťϙ«ϟ ĺŜťϱĖČϙŘĺèôîŪŘôϡ ®ôīīϙŪŕŕĺŘť ͑͘ϟ "ϙıŪîϙæĺÍťϟϙ"ϙi(ϙēĺŪŜôϟϙaĺŽôϙťĺϙIJôƄťϙſôīīϙīĺèÍťĖĺIJϟ ͒͏ϟ ϙèŘÍIJôϟϙb"ϙi(ϟ ͒͐ϟ b͓ϱ͐ϯ͕͐Ћϙ͔aϙťŘôôϟϙôŜťϙťŪæĖIJČϙēÍIJČôŘϙŽĺĖîϙťĺϙ͔͏͏ϙŕŜĖϙīĺſϯ͔Ϡ͏͏͏ϙŕŜĖϙēĖČēϟϙŪīīϙ«ϟ ͒͑ϟ "ϙèŘÍIJôϟϙaĺŽôϙ͔͏͏ϙææīϙŘôťŪŘIJŜϙťÍIJħϙÍIJîϙŘĖČϙıÍťŜϙťĺϙIJôƄťϙſôīīϙīĺèÍťĖĺIJϟ ͒͒ϟ ŪŘIJϙſôīīϙĺŽôŘϙťĺϙŕŘĺîŪèťĖĺIJϟϙϙſôīīϙēĺŪŜôϙÍIJîϙċīĺſīĖIJôŜϟ ťťÍèēıôIJťŜϡ ͐ϟ ŜϱæŪĖīťϙèēôıÍťĖè ͑ϟ ŘĺŕĺŜôîϙèēôıÍťĖè ͒ϟ i(ϙèēôıÍťĖè _____________________________________________________________________________________ Revised By: DLW 5/2/2022 SCHEMATIC Milne Point Unit Well: MPU K-33 Last Completed: 8/11/2011 PTD: 196-202 TD = 11,543’ (MD) / TD = 9,310’(TVD) 20” Orig. KB Elev.: 61.8’/ GL Elev.: 27.8’ (N27E) 7” 3 4 5 6 7 10 9 9-5/8” 1 2 PBTD = 11,483’ (MD) / PBTD = 9,251’(TVD) KUP Sands 8 Sag Sands 11 XN CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 6,666’ 7" Production 26 / L-80 / Btrc 6.276 Surface 11,526’ TUBING DETAIL 4-1/2” Tubing 12.6 / 13 CR-85 / VAM 3.958 Surface 8,956’ 3-1/2” Tubing 9.2 / 13 CR-85 / VAM 2.992 8,956 9,703’ JEWELRY DETAIL No Depth Item 1 2,199’ 4-1/2” x 1” KBG-2 GLM 2 8,896’Opened 4/11/2020 4-1/2” HES XD Duro Sleeve: ID= 3.813” 3 8,928’ 4-1/2” X-Nipple: ID= 3.8/13” 4 8,956’ 4-1/2” x 3-1/2” Crossover 5 8,993’ 7” x 3-12” HES TNT Packer 6 9,306’Open 7-23-20 3-1/2” HES XD Duro Sleeve: ID= 2.813” 7 9,558’ 3-1/2” X-Nipple: ID= 2.813” 8 9,594’ 7” x 3-1/2” HES TNT Packer 9 9,625’ 3-1/2” X-Nipple: ID= 2.813” 10 9,691’ 3-1/2” XN-Nipple –No Go ID= 2.750”PXN plug set 7-23-20 11 9,703’ 3-1/2” 9Cr WLEG, TCII Box PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk 9,280’ 9,306’ 7,088’ 7,095’ 26 6/27/2001 Isolated Kuparuk 9,306’ 9,316’ 7,095’ 7,105’ 10 6/27/2001 Isolated Kuparuk 9,328’ 9,334’ 7,117’ 7,123’ 6 6/27/2001 Isolated Sag River Sands 11,374’ 11,394’ 9,143’ 9,162’ 20 6/27/2001 Open WELL INCLINATION DETAIL KOP @ 380’ Max Hole Angle = 58 deg. @ 3,840’MD Hole Angle thru perfs =7 Deg. Max DLS = 4.34 deg. @ 7,311’ MD TREE & WELLHEAD Tree 4-1/16” – 5M Cameron Wellhead 11” 5M FMC w/ 11” x 4-1/16” 5M Hanger w/ 4-1/2” TC-II Box Top, 4-1/16” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22729-00-00 Drilled and Cased by Nabors 27E - 2/11/1997 ESP Completion by Nabors 4-ES – 2/13/1997 RWO by Nabors 5-S – 2/24/1998 Conv. f/ Sag River to Kuparuk by Nabors 4-ES – 4/2/1999 RWO by Nabors 4-ES – 6/29/2001 RWO by Nabors 4-ES – 5/1/2004 RWO by Nabors 3S – 8/9/2008 RWO by Nabors 4-ES – 9/14/2010 RWO by Doyon 16 – 8/1/2011 Set PXN Plug and Shift to Kuparuk Producer – 7/23/2020 OPEN HOLE / CEMENT DETAIL 20” 250 sx Arcticset I in a 24” Hole 9-5/8” 1,950 sx PF ‘E’, 290 sx ‘G’, 100 sx PF ‘C’”in a 12.25” Hole 7” 550 sx Class “G” in a 8.5” Hole STIMULATION DETAIL Interval: 11,374’ to 11,394’ – 134,000 lbs. 20/40 Carbolite _____________________________________________________________________________________ Revised By: TDF 1/31/2025 PROPOSED Milne Point Unit Well: MPU K-33 Last Completed: 8/11/2011 PTD: 196-202 TD =11,543’ (MD) / TD = 9,310’(TVD) 20” Orig. KB Elev.: 61.8’/ GL Elev.: 27.8’ (N27E) 7” 4 5 6 9 8 9-5/8” 1 Tubing Cut @ ±8,960’ MD PBTD =11,483’ (MD) / PBTD = 9,251’(TVD) 3 KUP Sands 7 Sag Sands 10 2 XN CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 6,666’ 7" Production 26 / L-80 / Btrc 6.276 Surface 11,526’ TUBING DETAIL 4-1/2” Tubing 12.6 / 13 CR-85 / VAM 3.958 Surface 8,956’ 3-1/2” Tubing 9.2 / 13 CR-85 / VAM 2.992 8,956 9,703’ JEWELRY DETAIL No Depth Item 1 ±200’ 4-1/2” GLM w/ Orifice GLV Installed 2 ±8,700’ 4-1/2” GLM w/ Dummy GLV Installed 3 ±X,XXX’ 4-1/2” XN-Nipple 4 ±X,XXX’ ESP Assembly – Btm @ ±8,820’ 5 8,993’ 7” x 3-12” HES TNT Packer 6 9,306’Open 7-23-20 3-1/2” HES XD Duro Sleeve: ID= 2.813” 7 9,558’ 3-1/2” X-Nipple: ID= 2.813” 8 9,594’ 7” x 3-1/2” HES TNT Packer 9 9,625’ 3-1/2” X-Nipple: ID= 2.813” 10 9,691’ 3-1/2” XN-Nipple –No Go ID= 2.750”PXN plug set 7-23-20 11 9,703’ 3-1/2” 9Cr WLEG, TCII Box PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk 9,280’ 9,306’ 7,088’ 7,095’ 26 6/27/2001 Isolated Kuparuk 9,306’ 9,316’ 7,095’ 7,105’ 10 6/27/2001 Isolated Kuparuk 9,328’ 9,334’ 7,117’ 7,123’ 6 6/27/2001 Isolated Sag River Sands 11,374’ 11,394’ 9,143’ 9,162’ 20 6/27/2001 Open WELL INCLINATION DETAIL KOP @ 380’ Max Hole Angle = 58 deg. @ 3,840’MD Hole Angle thru perfs =7 Deg. Max DLS = 4.34 deg. @ 7,311’ MD TREE & WELLHEAD Tree 4-1/16”–5M Cameron Wellhead 11” 5M FMC w/ 11” x 4-1/16” 5M Hanger w/ 4-1/2” TC-II Box Top, 4-1/16” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22729-00-00 Drilled and Cased by Nabors 27E - 2/11/1997 ESP Completion by Nabors 4-ES –2/13/1997 RWO by Nabors 5-S –2/24/1998 Conv. f/ Sag River to Kuparuk by Nabors 4-ES –4/2/1999 RWO by Nabors 4-ES –6/29/2001 RWO by Nabors 4-ES –5/1/2004 RWO by Nabors 3S –8/9/2008 RWO by Nabors 4-ES –9/14/2010 RWO by Doyon 16 –8/1/2011 Set PXN Plug and Shift to Kuparuk Producer –7/23/2020 OPEN HOLE / CEMENT DETAIL 20” 250 sx Arcticset I in a 24” Hole 9-5/8” 1,950 sx PF ‘E’, 290 sx ‘G’, 100 sx PF ‘C’”in a 12.25” Hole 7” 550 sx Class “G” in a 8.5” Hole STIMULATION DETAIL Interval: 11,374’ to 11,394’ – 134,000 lbs. 20/40 Carbolite Milne Point ASR Rig 1 BOPE 2023 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250220 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 18RD 50133205840100 222033 1/27/2025 AK E-LINE Patch BRU 223-24 50283201830000 221072 1/26/2025 AK E-LINE Perf CLU 10RD 50133205530100 222113 11/2/2024 YELLOWJACKET PLUG GP 03-87 50733204370000 166052 12/16/2024 AK E-LINE Plug/Cement IRU 44-36 50283200890000 193022 1/22/2025 AK E-LINE Perf KU WD-01 50133203450000 181107 10/15/2024 YELLOWJACKET PERF MPI 1-29 50029216690000 186181 1/29/2025 AK E-LINE Perf MPU C-39 50029228490000 197248 1/27/2025 AK E-LINE TubingCut MPU E-20A 50029225610100 204054 2/1/2025 READ CaliperSurvey MPU K-33 50029227290000 196202 2/8/2025 AK E-LINE TubeCut MPU S-08 50029231680000 203123 2/6/2025 AK E-LINE CmtRtr/Punch MRU A-13 50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-02 50733203890000 187061 1/22/2025 AK E-LINE Perf MRU M-32RD2 50733204620200 217091 2/10/2025 AK E-LINE TubingPunch NCIU A-09 50883200290100 222024 1/31/2025 AK E-LINE Perf NCIU A-16 50883201270000 208098 1/30/2025 AK E-LINE Perf NCIU A-21 50883201990000 224086 1/15/2025 AK E-LINE Plug, Perf NK-41A 50029227780100 197158 1/6/2025 HALLIBURTON Coilflag PAVE 3-1 50029238060000 224140 1/4/2025 YELLOWJACKET CBL PBU P1-13 50029223720000 193074 12/3/2024 HALLIBURTON PPROF PTM P1-07A 50029219960100 204037 12/31/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T40127 T40128 T40129 T40130 T40131 T40132 T40133 T40134 T40135 T40136 T40137 T40138 T40139 T40140 T40141 T40142 T40143 T40144 T40145 T40146 T40147 MPU K-33 50029227290000 196202 2/8/2025 AK E-LINE TubeCut Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.20 14:09:18 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to ESP 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,543'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9,310' 11,483' 9,251' 1,029 N/A KUPARUK RIVER OIL & SAG RIVER OIL N/A Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT K-33 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 5/30/2024 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0375132 & ADL0375133 196-202 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22729-00-00 Hilcorp Alaska LLC C.O. 432E & 423 Length Size Proposed Pools: 112' 112' 9.2 / 13 CR-85 / VAM TVD Burst 9,703' MILNE POINT MD N/A 5,750psi 7,240psi 4,948' 9,593' 6,666' 11,526' 112' 20" 9-5/8" 7" 6,666' 11,526' todd.sidoti@hilcorp.com 777-8443 Perforation Depth MD (ft): See Schematic See Schematic 3-1/2" 4-1/2" 12.6 / 13 CR-85 / VAM 8,956' (2) HES TNT Packers and N/A 8,993 MD / 6,786 TVD & 9,594 MD / 7,381 TVD and N/A Todd Sidoti No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 7:49 am, May 01, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.04.26 15:30:22 - 08'00' Taylor Wellman (2143) 324-257 SFD 5/1/2024 DSR-5/1/24MGR25SEP2024 10-404 * BOPE pressure test to 2000 psi. * 8 year IC pressure test to be charted and recorded *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.26 07:58:10 -08'00'09/26/24 RBDMS JSB 100124 RWO – ESP Install Well: MPU K-33 Date: 25 Apr 2024 Well Name: MPU K-33 API Number: 50-029-22729-00-00 Current Status: SI JP Producer Pad: K-Pad Estimated Start Date: May 30, 2024 Rig: ASR 1 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-202 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Brian Glasheen (907) 564-5277 (O) (907) 545-1144 (M) Current Bottom Hole Pressure: 1698 psi @ 6689’ TVD 7/4/2023 SPBPS | 4.9 PPGE MPSP: 1029 psi Gas Column Gradient (0.1 psi/ft) Max Inclination (Sail Well): 58.5 deg @ 4861’ Min Restriction: 2.750” @ 9691’ (3.5” XN) Brief Well Summary: MPU K-33 was drilled and frac’d in January 1997 as a Sag producer. It is currently configured as a RC jet pump and since there is no power fluid available at K-pad we will convert the well to ESP and return to production. Notes Regarding Wellbore Condition x CMIT-TxIA to 3500 psi passed on 1/18/2016. Objective: Pull 4-1/2” upper completion, install a 3-1/2” ESP completion and return well to production. Pre-Rig Procedure (No sundry required): Slickline & Fullbore 1. MIRU SL and fullbore, pressure test lubricator to 250 psi low / 2000 psi high. 2. RIH and set plug in 4.5” X nipple @ 8928’. POOH. 3. Perform CMIT-TxIA to 2500 psi. 4. RIH and pull plug. 5. POOH and RDMO SL. Eline & Fullbore 6. Clear and level pad area in front of well. Spot rig mats and containment. 7. RD well house and flowlines. Clear and level area around well. 8. RU reverse out skid and 500 bbl returns tank. 9. MIRU eline and pressure test PCE to 250 psi low / 2000 psi high. 10. RIH with mechanical tubing cutter. 11. Correlate to tubing tally and cut below top connection on the 3.5” short joint at 8960’. POOH and RDMO eline. Charted and recorded 30 minute test. - mgr RWO – ESP Install Well: MPU K-33 Date: 25 Apr 2024 12. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. 13. Confirm well is dead. Contact the operations engineer if freeze protection is needed depending on ASR arrival. 14. RD fullbore pumpers and reverse out skid. 15. RU crane. Set BPV. ND tree and tubing head adapter. NU BOPE. 16. NU BOPE house. Spot mud boat. Brief RWO Procedure (Sundry Approval Required): 17. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines. 18. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ produced water prior to setting CTS. 19. Test BOPE to 250 psi Low/ 2,000 psi High, annular to 250 psi Low/ 2,000 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 3-1/2” and 4-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 20. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. 21. MU landing joint or spear, PU and recover tubing hanger. a. Recorded PU weight was 142k and SO was 107k. 22. POOH and lay down the 4-1/2” tubing. a. 4-1/2” is chrome and will require the associated handling equipment. b. Save all chrome joints and jewelry for inspection and re-use. 23. MU and RIH with 7” casing scraper assembly. 24. Scrape and clean out to 8900’. POOH. 25. RU spooler to install ESP cable. 26. PU new 3-1/2” ESP completion and run to 8820’: A ESP Assembly – Centralizer at 8820’ Pup Joint, 3-1/2" 1 Joint Tubing, 3-1/2" B Pup Joint, 3-1/2” 3-1/2” GLM at ~8700’ – Dummy GLV Installed Pup Joint, 3-1/2” Joints Tubing, 3-1/2" C Pup Joint, 3-1/2" 3-1/2” GLM at ~ 200’ Orifice GLV Installed Pup Joint, 3-1/2" RWO – ESP Install Well: MPU K-33 Date: 25 Apr 2024 Joints Tubing, 3-1/2" D Space Out Pups, 3-1/2" 1 Joint Tubing, 3-1/2" 27. Space out, terminate ESP cable and land hanger. 28. Set BPV. Post-Rig Procedure: Well Support 29. RD mud boat. RD BOPE house. Move to next well location. 30. RU crane. ND BOPE. 31. NU 3-1/8” 5M tree. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 32. RD crane. Move 500 bbl returns tank and rig mats to next well location. 33. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By: DLW 5/2/2022 SCHEMATIC Milne Point Unit Well: MPU K-33 Last Completed: 8/11/2011 PTD: 196-202 TD = 11,543’ (MD) / TD = 9,310’(TVD) 20” Orig. KB Elev.: 61.8’/ GL Elev.: 27.8’ (N27E) 7” 3 4 5 6 7 10 9 9-5/8” 1 2 PBTD = 11,483’ (MD) / PBTD = 9,251’(TVD) KUP Sands 8 Sag Sands 11 XN CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 6,666’ 7" Production 26 / L-80 / Btrc 6.276 Surface 11,526’ TUBING DETAIL 4-1/2” Tubing 12.6 / 13 CR-85 / VAM 3.958 Surface 8,956’ 3-1/2” Tubing 9.2 / 13 CR-85 / VAM 2.992 8,956 9,703’ JEWELRY DETAIL No Depth Item 1 2,199’ 4-1/2” x 1” KBG-2 GLM 2 8,896’Opened 4/11/2020 4-1/2” HES XD Duro Sleeve: ID= 3.813” 3 8,928’ 4-1/2” X-Nipple: ID= 3.8/13” 4 8,956’ 4-1/2” x 3-1/2” Crossover 5 8,993’ 7” x 3-12” HES TNT Packer 6 9,306’Open 7-23-20 3-1/2” HES XD Duro Sleeve: ID= 2.813” 7 9,558’ 3-1/2” X-Nipple: ID= 2.813” 8 9,594’ 7” x 3-1/2” HES TNT Packer 9 9,625’ 3-1/2” X-Nipple: ID= 2.813” 10 9,691’ 3-1/2” XN-Nipple –No Go ID= 2.750”PXN plug set 7-23-20 11 9,703’ 3-1/2” 9Cr WLEG, TCII Box PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk 9,280’ 9,306’ 7,088’ 7,095’ 26 6/27/2001 Isolated Kuparuk 9,306’ 9,316’ 7,095’ 7,105’ 10 6/27/2001 Isolated Kuparuk 9,328’ 9,334’ 7,117’ 7,123’ 6 6/27/2001 Isolated Sag River Sands 11,374’ 11,394’ 9,143’ 9,162’ 20 6/27/2001 Open WELL INCLINATION DETAIL KOP @ 380’ Max Hole Angle = 58 deg. @ 3,840’MD Hole Angle thru perfs =7 Deg. Max DLS = 4.34 deg. @ 7,311’ MD TREE & WELLHEAD Tree 4-1/16” – 5M Cameron Wellhead 11” 5M FMC w/ 11” x 4-1/16” 5M Hanger w/ 4-1/2” TC-II Box Top, 4-1/16” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22729-00-00 Drilled and Cased by Nabors 27E - 2/11/1997 ESP Completion by Nabors 4-ES – 2/13/1997 RWO by Nabors 5-S – 2/24/1998 Conv. f/ Sag River to Kuparuk by Nabors 4-ES – 4/2/1999 RWO by Nabors 4-ES – 6/29/2001 RWO by Nabors 4-ES – 5/1/2004 RWO by Nabors 3S – 8/9/2008 RWO by Nabors 4-ES – 9/14/2010 RWO by Doyon 16 – 8/1/2011 Set PXN Plug and Shift to Kuparuk Producer – 7/23/2020 OPEN HOLE / CEMENT DETAIL 20” 250 sx Arcticset I in a 24” Hole 9-5/8” 1,950 sx PF ‘E’, 290 sx ‘G’, 100 sx PF ‘C’”in a 12.25” Hole 7” 550 sx Class “G” in a 8.5” Hole STIMULATION DETAIL Interval: 11,374’ to 11,394’ – 134,000 lbs. 20/40 Carbolite _____________________________________________________________________________________ Revised By: TDF 4/26/2024 PROPOSED Milne Point Unit Well: MPU K-33 Last Completed: 8/11/2011 PTD: 196-202 TD = 11,543’ (MD) / TD = 9,310’(TVD) 20” Orig. KB Elev.: 61.8’/ GL Elev.: 27.8’ (N27E) 7” 4 5 6 9 8 9-5/8” 1 Tubing Cut @ ±8,960’ MD PBTD = 11,483’ (MD) / PBTD = 9,251’(TVD) 3 KUP Sands 7 Sag Sands 10 2 XN CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 6,666’ 7" Production 26 / L-80 / Btrc 6.276 Surface 11,526’ TUBING DETAIL 4-1/2” Tubing 12.6 / 13 CR-85 / VAM 3.958 Surface 8,956’ 3-1/2” Tubing 9.2 / 13 CR-85 / VAM 2.992 8,956 9,703’ JEWELRY DETAIL No Depth Item 1 ±200’ 3-1/2” GLM w/ Orifice GLV Installed 2 ±8,700’ 3-1/2” GLM w/ Dummy GLV Installed 3 ±X,XXX’ ESP Assembly – Btm @ ±8,820’ 4 8,993’ 7” x 3-12” HES TNT Packer 5 9,306’Open 7-23-20 3-1/2” HES XD Duro Sleeve: ID= 2.813” 6 9,558’ 3-1/2” X-Nipple: ID= 2.813” 7 9,594’ 7” x 3-1/2” HES TNT Packer 8 9,625’ 3-1/2” X-Nipple: ID= 2.813” 9 9,691’ 3-1/2” XN-Nipple –No Go ID= 2.750”PXN plug set 7-23-20 10 9,703’ 3-1/2” 9Cr WLEG, TCII Box PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk 9,280’ 9,306’ 7,088’ 7,095’ 26 6/27/2001 Isolated Kuparuk 9,306’ 9,316’ 7,095’ 7,105’ 10 6/27/2001 Isolated Kuparuk 9,328’ 9,334’ 7,117’ 7,123’ 6 6/27/2001 Isolated Sag River Sands 11,374’ 11,394’ 9,143’ 9,162’ 20 6/27/2001 Open WELL INCLINATION DETAIL KOP @ 380’ Max Hole Angle = 58 deg. @ 3,840’MD Hole Angle thru perfs =7 Deg. Max DLS = 4.34 deg. @ 7,311’ MD TREE & WELLHEAD Tree 4-1/16” – 5M Cameron Wellhead 11” 5M FMC w/ 11” x 4-1/16” 5M Hanger w/ 4-1/2” TC-II Box Top, 4-1/16” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22729-00-00 Drilled and Cased by Nabors 27E - 2/11/1997 ESP Completion by Nabors 4-ES – 2/13/1997 RWO by Nabors 5-S – 2/24/1998 Conv. f/ Sag River to Kuparuk by Nabors 4-ES – 4/2/1999 RWO by Nabors 4-ES – 6/29/2001 RWO by Nabors 4-ES – 5/1/2004 RWO by Nabors 3S – 8/9/2008 RWO by Nabors 4-ES – 9/14/2010 RWO by Doyon 16 – 8/1/2011 Set PXN Plug and Shift to Kuparuk Producer – 7/23/2020 OPEN HOLE / CEMENT DETAIL 20” 250 sx Arcticset I in a 24” Hole 9-5/8” 1,950 sx PF ‘E’, 290 sx ‘G’, 100 sx PF ‘C’”in a 12.25” Hole 7” 550 sx Class “G” in a 8.5” Hole STIMULATION DETAIL Interval: 11,374’ to 11,394’ – 134,000 lbs. 20/40 Carbolite Milne Point ASR Rig 1 BOPE 2023 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 05/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU K-33 (PTD 196-202) MFC 05/04/2022 Please include current contact information if different from above. PTD:196-202 T36629 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.18 10:05:53 -08'00' 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Change Production Interval Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,543 feet N/A feet true vertical 9,310 feet N/A feet Effective Depth measured 11,483 feet 8,993 & 9,594 feet true vertical 9,251 feet 6,786 & 7,381 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 12.6 / 13 CR-85 / VAM 8,956' 6,750' Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2 / 13 CR-85 / VAM 9,703' 7,488' Packers and SSSV (type, measured and true vertical depth) (2) HES TNT Packers N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: WINJ WAG 0 Water-Bbl MD 112' 6,666' 11,526' TVD 112' 611 Oil-Bbl measured true vertical Packer 2,203 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 135 Casing Pressure 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 2210 MILNE PT UNIT K-33 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-202 50-029-22729-00-00 Plugs ADL0375132 5. Permit to Drill Number: MILNE POINT / KUPARUK RIVER OIL & SAG RIVER OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 248 Authorized Signature with date: Authorized Name: David Haakinson dhaakinson@hilcorp.com Tubing Pressure 108 N/A measured N/A Casing Conductor Size Junk measured Length 112' 6,666' 11,526' Surface Production N/A 5,750psi 7,240psi 20" 9-5/8" 7" 4,948' 9,293' 777-8343 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 3,090psi 5,410psi Burst Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 2:55 pm, Aug 06, 2020 Chad A Helgeson 2020.08.06 15:37:20 -05'00' RBDMS HEW 8/6/2020 DSR-8/6/2020 SFD 8/10/2020MGR30JUL2021 _____________________________________________________________________________________ Revised By: JCM 8/2/2020 SCHEMATIC Milne Point Unit Well: MPU K-33 Last Completed: 8/11/2011 PTD: 196-202 TD = 11,543’ (MD) / TD = 9,310’(TVD) 20” Orig. KB Elev.: 61.8’/ GL Elev.: 27.8’ (N27E) 7” 3 4 5 6 7 10 9 9-5/8” 1 2 PBTD = 11,483’ (MD) / PBTD = 9,251’(TVD) KUP Sands 8 Sag Sands 11 12X Jet Pump Set 7/01/19 SAG River XN CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 6,666’ 7" Production 26 / L-80 / Btrc 6.276 Surface 11,526’ TUBING DETAIL 4-1/2” Tubing 12.6 / 13 CR-85 / VAM 3.958 Surface 8,956’ 3-1/2” Tubing 9.2 / 13 CR-85 / VAM 2.992 8,956 9,703’ JEWELRY DETAIL No Depth Item 1 2,199’ 4-1/2” x 1” KBG-2 GLM 28,896’Opened 4/11/2020 4-1/2” HES XD Duro Sleeve: ID= 3.813”(JP sitting down in XO) 3 8,928’ 4-1/2” X-Nipple: ID= 3.8/13” 4 8,956’ 4-1/2” x 3-1/2” Crossover Jet pump stuck in XO with over shot on it See 8-1-20 WSR 5 8,993’ 7” x 3-12” HES TNT Packer 69,306’Open 7-23-20 3-1/2” HES XD Duro Sleeve: ID= 2.813” 7 9,558’ 3-1/2” X-Nipple: ID= 2.813” 8 9,594’ 7” x 3-1/2” HES TNT Packer 9 9,625’ 3-1/2” X-Nipple: ID= 2.813” 10 9,691’ 3-1/2” XN-Nipple –No Go ID= 2.750”PXN plug set 7-23-20 11 9,703’ 3-1/2” 9Cr WLEG, TCII Box PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk 9,280’ 9,306’ 7,088’ 7,095’ 26 6/27/2001 Isolated Kuparuk 9,306’ 9,316’ 7,095’ 7,105’ 10 6/27/2001 Isolated Kuparuk 9,328’ 9,334’ 7,117’ 7,123’ 6 6/27/2001 Isolated Sag River Sands 11,374’ 11,394’ 9,143’ 9,162’ 20 6/27/2001 Open WELL INCLINATION DETAIL KOP @ 380’ Max Hole Angle = 58 deg. @ 3,840’MD Hole Angle thru perfs =7 Deg. Max DLS = 4.34 deg. @ 7,311’ MD TREE & WELLHEAD Tree 4-1/16” – 5M Cameron Wellhead 11” 5M FMC w/ 11” x 4-1/16” 5M Hanger w/ 4-1/2” TC-II Box Top, 4-1/16” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22729-00-00 Drilled and Cased by Nabors 27E - 2/11/1997 ESP Completion by Nabors 4-ES – 2/13/1997 RWO by Nabors 5-S – 2/24/1998 Conv. f/ Sag River to Kuparuk by Nabors 4-ES – 4/2/1999 RWO by Nabors 4-ES – 6/29/2001 RWO by Nabors 4-ES – 5/1/2004 RWO by Nabors 3S – 8/9/2008 RWO by Nabors 4-ES – 9/14/2010 RWO by Doyon 16 – 8/1/2011 Set PXN Plug and Shift to Kuparuk Producer – 7/23/2020 OPEN HOLE / CEMENT DETAIL 20” 250 sx Arcticset I in a 24” Hole 9-5/8” 1,950 sx PF ‘E’, 290 sx ‘G’, 100 sx PF ‘C’”in a 12.25” Hole 7” 550 sx Class “G” in a 8.5” Hole STIMULATION DETAIL Interval: 11,374’ to 11,394’ – 134,000 lbs. 20/40 Carbolite Well Name Rig API Number Well Permit Number Start Date End Date MP K-33 Slick Line 50-029-22729-00-00 196-202 7/22/2020 7/23/2020 No operations to report. No operations to report. 7/25/2020 - Saturday No operations to report. 7/28/2020 - Tuesday 7/26/2020 - Sunday No operations to report. 7/27/2020 - Monday 7/24/2020 - Friday No operations to report. 7/22/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL, PT PCE 250L/2,500H. W/ GAUGE @ 8,877' SLM (8,896' MD. JET PUMP IN GOOD CONDITION, GOOD DATA ON GAUGE. RAN 4-1/2" 42BO SHIFTING TOOL & CLOSED XD SSD @ 8,875' SLM (8,896' MD). RAN 1.70" O.D. x 1' CROSS MAGNET OUT TTL TO 9,700' SLM. RECOVERED ~1/4 CUP METAL SHAVINGS. SET 3-1/2" PXN-PLUG BODY IN XN-NIP @ 9,675' SLM (9,691' MD). 7/23/2020 - Thursday WELL S/I ON ARRIVAL, PT PCE 250L/2,500H. SET P-PRONG IN 3-1/2" PXN-PLUG BODY @ 9,675' SLM (9,691' MD) (TOP OF P- PRONG @ 9,667' SLM). SAG SANDS ISOLATED. BLED TBG FROM 500 TO 100 PSI TO CONFIRM PLUG HOLDING. LOAD TBG W/ POWER FLUID & APPLY 350 PSI ON TBG BEFORE ATTEMPTING TO SHIFT KUP SANDS 3-1/2" XD SSD. RAN 3-1/2" 42BO SHIFTING TOOL, SHIFT 3-1/2" XD SSD OPEN @ 9,291' SLM (9,306' MD). TBG WENT ON VAC, KUP SANDS OPEN. RAN 2.50" O.D. x 1' CROSS MAGNET TO TOP OF P-PRONG @ 9,967' SLM. ~1/4 CUP FINE METAL SHAVINGS RECOVERED. RAN 4-1/2" 42BO SHIFTING TOOL, SHIFT 4-1/2" XD SSD OPEN @ 8,875' SLM (8,896' MD). SET 3" JET PUMP (sn# HC-00030, ratio=12X, nozzle=12, throat=11) W/ SCREEN IN 4-1/2" XD SSD @ 8,875' SLM (8,896' MD). MISSING 1 BRASS NUBBIN FROM X-LINE. RAN 4-1/2" CHECK SET TO JET PUMP @ 8,875' SLM (8,896' MD). CONFIRMED JET PUMP SET. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / q~-~c~L File Number of Well History File PAGES TO DELETE RESCAN Complete [] Color items - Pages: GraYScale, halftones, pictures, graphs, charts - Pages: q/~"/7,,~C-~7' [] Poor Quality Odginal- Pages: [] Other- Pages' . DIGITAL DATA D Diskettes, No. Other, No/Type 'OVERSIZED .Logs of various kinds Other COMMENTS: n Scanned. ~~,~.D~r~ TO RE-SCAN Notes: Nathan Low~ll Date: Is/~ • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 _ E . EE1 t II L1 Mr. Tom Maunder Ct 6— " oti 0 9 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 1-f 35 Anchorage, Alaska 99501 l Subject: Corrosion Inhibitor Treatments of MPK -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPK -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPK 10/29/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPK -02 1960810 50029226750000 0.2 NA 0.2 NA 5.1 9/5/2011 MPK -05 1960680 50029226700000 1.9 NA 1.9 NA 17.9 8/24/2011 MPK-06 1961910 50029227250000 1.5 NA 1.5 NA 8.5 8/27/2011 MPK-09 2050140 50029232470000 1.9 NA 1.9 NA 12.8 8/24/2011 MPK -13 1960400 50029226550000 1.7 NA 1.7 NA 14.5 8/24/2011 MPK -17 1960280 50029226470000 1 NA 1 NA 2.6 8/24/2011 MPK -18A 1970270 50029227330100 4.6 NA 4.6 NA 23.8 8/27/2011 MPK -21A 2031620 50029227180100 0.4 NA 0.4 NA 6.9 10/29/2011 MPK -22 2050220 50029232490000 2 NA 2 NA 5.1 8/27/2011 MPK -25 1960320 50029226500000 4.2 NA 4.2 NA 30.6 8/24/2011 MPK -30 1961680 50029227110000 1.5 NA 1.5 NA 17.0 8/25/2011 - --} MPK-33 1962020 50029227290000 1.7 NA 1.7 NA 15.3 8/24/2011 MPK-34 1961690 50029227120000 2.5 NA 2.5 NA 25.5 8/25/2011 MPK-37 1960760 50029226740000 2 NA 2 NA 17.0 8/24/2011 MPK -38 1960300 50029226490000 3.2 NA 3.2 NA 15.3 8/25/2011 MPK -43A 1970410 50029227380100 1.7 NA 1.7 NA 13.6 9/16/2011 STATE OF ALASKA • • ALAS AND GAS CONSERVATION COMMIS REPOR SUNDRY WELL OPERAT NS 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Replace ESP with Jet Pump 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. Development ❑ Exploratory r 196 - 202 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 - 50 - 029 - 22729 - 00 - 00 7. Property Designation: 8. Well Name and Number: ADL 375132 & 375133 _ MPK 9. Field / Pool(s): � � -�� �� % % Milne Point Unit / Kuparuk River Sands vV 10. Present well condition summary Total depth: measured 11543' feet Plugs (measured) None feet true vertical 9310' feet Junk (measured) None feet Effective depth: measured 11483 feet Packer: (measured) 8993' / 9594' feet true vertical 9251' feet Packer: (true vertical) 6786' / 7381' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 112' 112' Surface 6630' 9-5/8" 6666' 4948' 5750 3090 Intermediate Production 11492' 7" 11526' 9293' 7240 5410 Liner „t'c ;0., .E0 SEP el 6, 201 Perforation Depth: Measured Depth: 11374' - 11394' True Vertical Depth: 9142' - 9162' Tubing (size, grade, measured and true vertical depth): 4-1/2" x 3 -1/2 ", 12.6# / 9.2# 13Cr - 9704' MD 7489' TVD Packers and SSSV (type, measured and true vertical depth): 7" x 3 HES TNT Packer 8993' MD 6786' TVD 7" x 3-1/2" HES TNT Packer 9594' MD 7381' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): RECEIVED' Treatment description including volumes used and final pressure: AUG 3 0 2011 taittict OW & Gas Cos. Commission 12. Representative Daily Average Production or 14 '1511? Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory ® Development ❑ Service ❑ Stratigraphic IS Daily Report of Well Operations El Schematic Diagram 15. Well Status after work: ❑ GINJ 011 ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Wilmer Hoffman, 564 -4592 N/A Printed Name Elizabeth Barker Title Drilling Technologist Ph 564-5674 Date Prepared By Name/Number. Signature ��� 69/x // El izabeth Barker, 564-5674 Form 10-404 Revi r : 010 Submit Original Only RBDMS AUG 31 2011 4-11)-t-x • MPK -33, Well History (Pre Rig RWO) Date Summary 9 -Jul -2011 RAN SBHPS W/ DUAL SPARTEK GAUGES, 30 MIN GRADIENT STOP @ 10522' MD & 3 HOUR STOP @ 11027' MD PULLED BK -DGLV FROM LOWER GLM CO 11087' SLM/ 11095' MD "LEFT POCKET OPEN" PULLED BK -OGLV FROM UPPER GLM @ 154' SLM/ 171' MD & SET BK -DGLV ASSIST WELL SUPPORT W/ INSTALLING BPV. 10 -Jul -2011 Tested barriers, rigged up to well. Pressure tested lubricator to 300 psi & 3500 psi for 5 min (charted). Set 2- 9/16" CIW H BPV thru tree, tagged @ 114 ", pre RWO. Rigged up to frontside I/A with VR lubricator and tested to 300 psi and 3500 psi (charted). Set 2- 1/16" FMC VR plug, removed I/A and installed a tapped blind flange. Tested flange to 500 psi and 4500 psi (charted & recorded). Pressure tested tree cap to 500 psi. Removed well house, flowlines and foundation. 16 -Jul -2011 PPPOT -T : RU 1 HP BT onto THA 50 psi bled to 0 psi. Pressured to 5000 psi for 30 minute test, 5000/ 15 min, 5000/ 30 min. Bled void to 0 psi, cycle and torqued LDS "Et style" all were in good working and visual condition. PPPOT -IC : RU 2 HP BT onto IC test void 0 psi. Flushed void until clean returns achieved, pressured to 3500 psi for 30 minute test, 3500/ 15 min, 3500/ 30 min. Bled void to 0 psi, cycle and torqued LDS "ET style" all were in good working and visual condition. Page 1 of 1 • • TREE: 4 -1/16" - 5M Cameron M P K -33 Orig. KB Elev. = 61.8 (N27E) WELLHEAD:11" 5M FMC Orig. GL Elev. = 27.8 (N27E) w/ 11 "x 4 -1/16" 5M Hanger w/ 4 1/2" TC-Il Box Orig. KB to BF = 19.8 (N4ES) Top, 4- 1/16" CIW H BPV profile Conductor Casing I 112' 4 -1/2" by 1" KBG -2 GLM 2199' 9 5/8" 40 ppf L -80 casing 6666' , , 'Reverse Cirwlafinn' Jet Pump Configuratlon KOP @ 380' - p.a .' ud <; s Sek Max Hole Angle: 58° @ 3840' MD ' i Q Angle thru pen 6 s = 7° 1 a 1 iA w . e I r °--- Max DLS = 4.34° @ 7311' MD i - I I - • 2, .E 3 4 1/2" 12.6 ppf 13Cr -85 VAM Top tubing —'� ( drift ID = 3.833 ", cap. = 0.0152 bpf) , '' 3 1/2" 9.6 ppf 13Cr -85 VAM Top tubing ReseNei,Eiuia ( drift ID = 2.867 ", cap. = 0.0087 bpf ) 7" 26 ppf, L -80, BTC. prod. casing 4 -1/2" HES XD 8896` ( drift ID = 6.151 ", cap. = 0.0383 bpf) Duro Sleeve 3.813" id ( cap. of IA w/ tbg inside = 0.0186 bpf) a I 4 -1/2" X Nipple at 3.813" id 8928` ER 4 -1/2" X 3 1/2" Crossover 1 8956` 7" X 3 -1/2" HES TNT Packer 8993` Stimulation Summa 3 - 1/2" HES XD rY Duro Sleeve 2.813" id Perforation Summary 9306' Ref log: GRJCCL 01/29/97 ED 3 -1/2" X Nipple at 2.813" id 9558' Size SPF Interval (TVD) 4.5" 5 9280 - 9306 X�70'�888' -7095' 7" X 3-1/2" HES TNT Packer 9594` 33/8,' * S EZ C7 -7105' 3 3/8" 4 9328 - 9334 7117' -7123' ED 3-1/2" X Nipple at 2.813" id ( 9625' 'shot 6/27/01 w/ Schlumberger Powerjet guns 3 -1/2" XN 2.813" id Nipple 15 bbls, 75 sx "G" 15.8# cement (2.750" No-go ID) 9691' - 3 -1/2" 9Cr WLEG, TCII Box 9703` Sag River Perforations: Size SPF Interval ND) I a 4.5" 6 11374•- 11394' 9143' -9162' 7" float collar (PBTD) I 11483' .:----------.4.1.-:.------•--..; 7" 26 ppf L -80 BTRS f 11525' I DATE REV. BY COMMENTS 02/13/97 MDO ESP Completion 4 -ES MILNE POINT UNIT 02/24/98 M. Linder RWO 5 -S WELL K -33 04/02/99 JWS Conversion from Sad River to Kuparuk 4ES 06/29/01 B. Hasebe RWO Nabors 4ES API NO: 50- 029 -22729 05/01/04 Lee Hulme RWO Nabors 4 -ES 08/09/08 Lee Hulme RWO Nabors 3S , 09/14/10 J. Perl RWO Nabors 4 -ES 08/01/11 Brian Bixby RWO Doyon 16 BP EXPLORATION (AK) • • North America - ALASKA - BP Page 1 of 11 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2011 End Date: X4- 00V3F -E: (2,250,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/9/1997 12:00:00AM Rig Release: 8/1/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292272900 Active Datum: 22 : 33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/20/2011 18:00 - 21:00 3.00 MOB P PRE MOBILIZE OF W PAD ONTO W PAD ACCESS ROAD DRIVE DOWN ACCESS ROAD TOWARDS SPINE ROAD 21:00 - 00:00 3.00 MOB P PRE TURN ONTO GPB SPINE ROAD AND DRIVE TOWARDS MPU STOP AT Z PAD ENTRANCE AND ALLOW RIG MATS TO BE MOVED AROUND RIG 7/21/2011 00:00 - 06:00 6.00 MOB P PRE MOBILIZE FROM Z PAD ROAD DOWN SPINE • ROAD STOPATMPU /GPB "Y" CHANGE OUT TOOL PUSHERS, NOTIFY MPU 06:00 08:00 2.00 MOB P ■- PRE A Y CHANGE OUT PUSHERS, ALLOW MPU MPU TRRAFFIC BY WAIT ON RIG MAT SHUFFLE 08:00 - 12:00 4.00 MOB P -_ PRE DRIVE DOWN MPU SPINE TO TEXACO PAD AND STAGE THERE 12:00 - 19:30 7.50 MOB P PRE STAGE RIG MATTS AGAIN -LAY OUT MATTS ON SPINE ROAD SOFT SPOTS -START LAYING MATTS ON K PAD ACCESS ROAD 19:30 - 00:00 4.50 MOB P -_ PRE DRIVE DOWN MPU SPINE TO K PAD ACCESS ROAD 7/22/2011 00:00 - 00:30 0.50 MOB PRE TURN ONTO K PAD ACCESS ROAD AT ABOUT 300 TO 400 FT IN JUST PRIOR TO GETTING ONTO RIG MATTS RIG STARTED TO BLOW OUT ROAD. -BACK OUT OF IT OK. 00:30 - 04:30 4.00 MOB PRE LAY RIG MATTS BEHIND RIG BACK UP ONTO AND PAST MATTS FILL IN HOLES MOVE RIG MATTS INTO PLACE 04:30 - 00:00 19.50 MOB PRE CONTINUE DOWN K PAD ACCESS ROAD TO THE END OF RIG MATTS DOUBLE STACK MATTS BEHIND THE RIG BACK UP TO END OF MATTS LAY OUT MATTS IN FRONT OF RIG DRIVE TO THE END OF THE MATTS DOUBLE STACK MATTS BEHIND THE RIG BACK UP TO THE END OF MATTS LAY OUT MATTS IN FRONT OF THE RIG DRIVE TO THE END OF THE MATTS -NOW ABOUT A LITTLE OVER 1/3 OF THE DISTANCE DOWN ACCESS ROAD 7/23/2011 00:00 - 07:30 7.50 MOB P PRE LAY OUT MATT BOARDS IN FRONT OF RIG Printed 8/30/2011 10:36:33AM •rth America - ALASKA - BP Page 2 of 11 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2011 End Date: X4- 00V3F -E: (2,250,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No : DOYON 16 Spud Date/Time: 1/9/1997 12:00:00AM Rig Release: 8/1/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292272900 Active Datum: 22 :33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 00:00 16.50 MOB P PRE DRIVE DOWN K PAD ACCESS ROAD TO THE END OF RIG MATTS DOUBLE STACK MATTS BEHIND THE RIG BACK UP TO END OF MATTS LAY OUT MATTS IN FRONT OF RIG DRIVE TO THE END OF THE MATTS DOUBLE STACK MATTS BEHIND THE RIG BACK UP TO THE END OF MATTS LAY OUT MATTS IN FRONT OF THE RIG DRIVE TO THE END OF THE MATTS DOUBLE STACK MATTS BEHIND THE RIG BACK UP TO THE END OF MATTS LAY OUT MATTS IN FRONT OF THE RIG PULL FORWARD TO THE END OF THE MATTS -NOW ABOUT A LITTLE OVER 1/2 OF THE DISTANCE DOWN ACCESS ROAD 7/24/2011 00:00 - 06:00 6.00 MOB P PRE TRIPLE STACK RIG MATTS BEHIND RIG BACK RIG UP TO END OF MATTS LAY OUT SINGLE MATTS IN FRONT OF RIG 06:00 - 00:00 18.00 MOB P PRE DRIVE FORWARD TO END OF RIG MATTS TRIPLE STACK RIG MATTS BEHIND RIG BACK UP RIG TO SINGLE MATS AT END LAY OUT RIG MATT SINGLES IN FRONT OF RIG DRIVE FORWARD TO END OF RIG MATTS TRIPLE STACK RIG MATTS BEHIND RIG BACKUP RIG TO SINGLE MATS AT END LAY OUT RIG MATT SINGLES IN FRONT OF RIG DRIVE FORWARD TO END OF RIG MATTS TRIPLE STACK RIG MATTS BEHIND RIG BACKUP RIG TO SINGLE MATS AT END LAY OUT RIG MATT SINGLES IN FRONT OF RIG DRIVE FORWARD TO END OF RIG MATTS TRIPLE STACK RIG MATTS BEHIND RIG 7/25/2011 00:00 - 06:00 6.00 MOB P PRE CONTINUE TO TRIPLE STACK RIG MATTS BEHIND RIG BACK UP RIG TO THE END OF MAT BOARDS TO SINGLE LAY OUT RIG MATTS IN FRONT OF RIG, RIG IS AT 2.4 MILES OUT OF 3.6 MILES 06:00 - 18:00 12.00 MOB P PRE PULL RIG TO FRONT OF MATTS AND CONTINUE TO LEAP FROG ONTO PAD 18:00 - 00:00 6.00 MOB P PRE PULL RIG ONTO PAD! CONTINUE TO LAY OUT RIG MATTS ACCROSS LOCATION - RIG WILL STAY ON RIG MATTS THE ENTIRE TIME IT'S ON K PAD DERRICK UP REMOVE BOOSTERS AND LOAD BOP STACK ONTO TRANSPORT STUMP 7/26/2011 00:00 - 01:30 1.50 RIGU P DECOMP ACCEPT RIG TO MPK -33 AT 00:00 SPOT RIG OVER MPK -33 AND SHIM Printed 8/30/2011 10:36:33AM rth America - ALASKA - BP Page 3 of 11 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2011 End Date: X4- 00V3F -E: (2,250,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/9/1997 12:00:00AM Rig Release: 8/1/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292272900 Active Datum: 22 : 33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 06:00 4.50 RIGU P DECOMP SPOT IN RIG EQUIPMENT AND RU -SPOT IN FLOW BACK TANK -SPOT IN SLOP TANK -SPOT IN GENERATOR -SPOT IN CHANGE TRAILER RU LINES TO TREE FOR WELL KILL OPPS RU HARD LINE FROM RIG TO FLOW BACK TANK SENDING WSL BLAST RESISTANT TRAILER TO LOCATION PROBABLY WILL NOT BE AVAILABLE FOR VIDEO CONFERENCE, BUT PHONES AT 659 -4168 WILL BE WORKING 06:00 - 09:00 3.00 RIGU P DECOMP GATHER CASING TOOLS TO RIG FLOOR - INSTALL RIG TONGS, ELEVATORS, SLIPS AND LIFTING EQUIPMENT - CHANGE OUT SAVER SUB TO HT 38 -TEST CIRCULATING LINE FROM PUMP TO _ CHOKE MANIFOLD TO 3500 PSI 09:00 - 12:00 3.00 KILLW P DECOMP TEST HARDLINE FROM CHOKE MANIFOLD TO FLOWBACK TANK TO 3500 PSI -BRING ON 380 BBLS OF 8.4 PPG SEAWATER 12:00 - 16:00 4.00 KILLW P DECOMP RIG UP DSM LUBRICATOR - PRESSURE TEST 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES -WHP: 0 PSI OA, 1800 PSI IA, 1800 PSI TUBING -PULL BPV -SHUT IN WELL AT TREE - RIG DOWN DSM LUBRICATOR 16:00 - 18:00 2.00 KILLW P DECOMP PJSM: BLEED GAS FROM IA AND TUBING -OPEN UP IA AND TUBING TO CLOSED CHOKE - PRESSURE 1800 PSI -START BLEEDING PRESSURE AT 75 -80 PSI DOWNSTREAM OF CHOKE 18:00 - 19:00 1.00 KILLW P DECOMP CONTINUE BLEEDING GAS -SHUT IN CHOKE, CHECK FLOWBACK TANK FOR RETURNS, TANK EMPTY - RESUME BLEEDING GAS: 70 PSI DOWNSTREAM OF CHOKE 19:00 - 19:15 0.25 KILLW P DECOMP CALL AOGCC INSPECTOR CHUCK SCHEEVE WITH UPDATE ON INITIAL BOPE TEST TIMING -CALL IN THE MORNING AT 6 AM WITH ANOTHER UPDATE 19:15 - 20:00 0.75 KILLW P DECOMP CONTINUE BLEEDING GAS -1000 PSI ON IA, 70 PSI DOWNSTREAM OF CHOKE 20:00 - 20:15 0.25 KILLW P DECOMP SHUT IN CHOKE TO CHECK FLOWBACK TANK - FLOWBACK TANK EMPTY - GAINED 70 PSI IN 10 MIN OF CHOKE BEING SI 20:15 - 22:00 1.75 KILLW P DECOMP CONTINUE BLEEDING GAS -CHOKE MANIFOLD IA PRESSURE DROPPED FROM 960 TO 490 PSI 22:00 - 22:15 0.25 KILLW P DECOMP SHUT IN CHOKE TO CHECK FLOWBACK TANK - FLOWBACK TANK HAS TRACE FLUID IN THE BOTTOM Printed 8/30/2011 10:36:33AM •rth America - ALASKA - BP Page 4 of 11 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2011 End Date: X4- 00V3F -E: (2,250,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/9/1997 12:00:00AM Rig Release: 8/1/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292272900 Active Datum: 22 : 33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:15 - 00:00 1.75 KILLW P DECOMP CONTINUE BLEEDING GAS FROM TUBING AND IA - OPENING CHOKE CHOKE PANEL PRESSURE DROPS FROM 480 TO 75 PSI -FULL OPEN CHOKE AND PRESSURE STABLIZED AT 70 -80 PSI FOR 30 MIN -LINE UP TO PUMP DOWN TUBING WITH RETURNS UP IA -PUMP 70 BBLS AT 5 BPM DOWN TUBING AND UP IA, MINIMAL GAS CUT RETURNS -LINE UP TO BULLHEAD DOWN TUBING AND IA 7/27/2011 00:00 - 00:30 0.50 KILLW P DECOMP BULLHEAD 107 BBLS AT 7 BPM DOWN IA AND TUBING WHEN PRESSURED UP TO 1980 PSI -BACK RATE DOWN TO 4 BPM TO STAY BELOW 2000 PSI - CONTINUE TO PUMP TO 169 TOTAL BBLS BULLHEADED - DETERMINED THAT UNABLE TO BULLHEAD AT SUFFICIENT RATE TO PUSH GAS OUT OF WELLBORE WITH A 2000 PSI LIMITATION. 00:30 - 01:00 0.50 KILLW P DECOMP SHUT IN IA AND BULLHEAD 25 BBLS DOWN TUBING AT 5 BPM - PRESSURE CLIMBED FROM 0 TO 2000 PSI DURING TUBING BULLHEAD 01:00 - 03:00 2.00 KILLW P DECOMP LINE UP TO CIRCULATE DOWN TUBING TAKING RETURNS UP IA THROUGH CHOKE AND GASBUSTER TO CUTTINGS BOX -SICP 340 PSI, 0 PSI SITP -BRING ON PUMP AT 2.5 BPM -GAS AND DIESEUSEA WATER RETURNS - INCREASE PUMP RATE TO 4 BPM AT 640 PSI TUBING PRESSURE WHILE MAINTAINING CASING PRESSURE CONSTANT -30% RETURNS AT 4BPM -WHEN GAS RATE DIMINISHED, INCREASED PUMP RATE TO 5BPM AT 1610 TUBING PSI -60% RETURNS AT 5 BPM -CLEAN FLUID RETURNS -8.4 PPG IN, 8.4 PPG OUT - CIRCULATED TOTAL OF 510 BBLS 03:00 - 03:30 0.50 KILLW P DECOMP SHUT DOWN PUMP AND MONITOR WELL FOR 30 MINUTES -WELL STATIC -4 BBLS TO FILL HOLE AFTER 30 MIN SI, 8 BPH STATIC LOSS RATE 03:30 - 05:00 1.50 KILLW P DECOMP CIRCULATE BOTTOMS UP OF 310 BBLS -45 -60 BPM DYNAMIC LOSS RATE 05:00 - 05:30 0.50 KILLW P DECOMP HOLD AAR FOR WELL KILL - ACTION ITEMS ARE HAVE SITE CONTROL SPECIALIST DIRECT VAC TRUCK DRIVERS TO CHECK IN WITH PITWATCHERAND PITWATCHERS TO RECORD TRUCK DRIVERS HARMONY NUMBERS ON WHITE BOARD FOR EASY ACCESS AND CHANGEOUT. 05:30 - 09:00 3.50 WHSUR P DECOMP INSTALL TWC -TEST FROM ABOVE TO 250 PSI LOW, 3500 PSI HIGH FOR 10 MIN - -GOOD TESTS 500 PSI ROLING TEST FROM BELOW AT 1.5 BPM, 630 PSI AND 29 BBLS AWAY IN 10 MIN - -GOOD TEST Printed 8/30/2011 10:36:33AM •rth America - ALASKA - BP Page 5 of.11 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2011 End Date: X4- 00V3F -E: (2,250,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/9/1997 12:00:00AM Rig Release: 8/1/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292272900 Active Datum: 22 : 33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 09:30 0.50 WHSUR P DECOMP BLEED DOWN ALL CIRCULATING LINES -FMC PREP FOR TREE REMOVAL 09:30 - 10:30 1.00 WHSUR P DECOMP ND TREE AND ADAPTOR FLANGE 10:30 - 14:30 4.00 WHSUR P DECOMP FIT NEW FMC GUIDE FOR SETTING TWC IN OFF - CENTER HANGER -RIG UP GUIDE AND FIT TO LUBRICATOR AND HANGER -FILL THE IA WITH 8.4 PPG FLUID AT 30 BPH 14:30 - 17:00 2.50 WHSUR P DECOMP NU BOPE 17:00 - 17:10 0.17 WHSUR P DECOMP AOGCC INSPECTOR CHUCK SCHEEVE WAIVED WITNESS OF INITIAL BOP TEST. 17:10 - 19:00 1.83 WHSUR P DECOMP TEST BOPE TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINUTES. TESTS WITNESSED BY BP WSL AND DD TP. 19:00 - 19:30 0.50 WHSUR P DECOMP CREW MEMBER IN CELLAR NOTICED BUBBLING IN SURFACE CASING BY CONDUCTOR ANNULUS -WSL AND DRILLER INSPECTED BUBBLING EVERY 1 -2 SECONDS FROM ONE LOCATION IN ANNULUS DIRECTLY BELOW ANNULAR VALVES -USED GAS DETECTOR TO TEST AIR IN ANNULUS, NO LELS, SAME COCENTRATIONS AS AIR -15 PSI ON OA, BLEED DOWN AND KEPT OA OPEN TO SLOP TANK -HAND IN CELLAR TO CONTINUE TO MONITOR - CALLED NS SUPT TO NOTIFY AND PROCEED WITH BOP TESTING /� 19:30 - 00:00 4.50 WHSUR P DECOMP CONTINUE BOP TESTING ((;{" TEST BOPE PER WELL PLAN, PERMIT TO 1 • q t DRILL, AND AOGCC REGS. -RAMS TESTED TO 250 PSI LOW AND 3500 PSI HIGH. -TEST USING 4 -1/2" AND 2 -7/8" TEST JOINTS. - PRESSURE TEST FOR 5 CHARTED MIN. -ALL TEST WITNESSED BY BP WSL / DDI TP. -ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT - AK -10 -45 -ON FLOOR VALVE FOR 2 -7/8" INITIAL FAILURE TO TEST TO 3500 PSI, RETORQUED CROSSOVER AND VALVE PASSED. ACCUMULATOR TEST: - ACCUMULATOR PRESSURE: 2900 PSI, MANIFOLD PRESSURE: 1500 PSI, ANNULAR PRESSURE: 800 PSI -DRAW DOWN = 1850 PSI -200 PSI INCREASE IN 12 SEC -FULL INCREASE TO 2850 PSI IN 70 SEC -5 BOTTLES OF N2 AT 1850 PSI Printed 8/30/2011 10:36:33AM Page 6 of 11 OM America - ALASKA - BP Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2011 End Date: X4- 00V3F -E: (2,250,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/9/1997 12:00:00AM Rig Release: 8/1/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292272900 Active Datum: 22 : 33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/28/2011 00:00 - 03:00 3.00 WHSUR P DECOMP RIG UP DUTCH RISER, DSM LUBRICATOR - MEASURE SPACE OUT WITH EXTENSION RODS AND DUMMY PLUG WITH BLINDS SHUT TO MAKE SURE THE PLUG COULD BE PULLED ABOVE THE BLINDS IF NEED TO SHUT THEM - PRESSURE TEST LUBRICATOR TO 250 PSI LOW /3500 PSI HIGH FOR 5 CHARTED MINUTES- -PASS -PULL TWC THROUGH FMC FUNNEL, WELL ON STRONG VAC -RIG DOWN DSM LUBRICATOR -HOLE FILL DOWN KILL LINE, 8 BBLS TO FILL WHEN DOWN FOR 30 MIN -16 BPH LOSSES 03:00 - 03:45 0.75 PULL P DECOMP PU LANDING JOINT - THREAD IN LANDING JOINT THROUGH FMC FUNNEL, COUNT 8 TO MAKE UP -MAKE UP TOP OF LANDING JOINT TO TOP DRIVE -BOLDS _ -PULL HANGER. OFF SEAT AT 130K LBS 03:45 - 05:00 1.25 PULL P DECOMP CIRCULATE BOTTOMS UP, 310 BBLS AT 5 BPM AT 1720 PSI -RIG UP DOUBLE SHEAVE, ELEPHANT TRUNK AND SLB SPOOLER - MONITOR WELL FOR 20 MIN, 40 BPH STATIC LOSS RATE 05:00 - 06:00 1.00 PULL P DECOMP PULL HANGER TO RIG Fl OOR -LAY DOWN LANDING JOINT AND TUBING HANGER. -RIG UP TO START ESP CABLE, CHEMICAL INJECTION LINE AND HEAT TRACE INTO SPOOLS. 06:00 - 08:00 2.00 PULL P DECOMP R/U DUAL SHEAVE. -LOOK FOR FIBER OPTIC CABLE FOR CAMERA. NO SUCCESS. 08:00 - 12:00 4.00 PULL P DECOMP POOH RACKING BACK 2 -7/8" EUE 8 RD TUBING IN DERRICK. -HOLD PJSM AND HAZARDOUS ASSESSMENT FOR SPOOLING UNIT AS NO CAMERA WILL BE IN USE DURING OPERATION. -POOH FROM 11,318' TO 9,498'. - REMOVE HEAT TRACE, CHEM LINE, ESP CLAMPS. -10:00 HRS TO 10:30 HRS: STOP AND HOLD AAR ON POOH WITH HANDS, ALSO DISCUSS DRIVING SAFETY WITH HANDS. - MAINTAIN CONTINUOUS HOLE FILL AT 20 BPH LOSS RATE. 12:00 - 20:00 8.00 PULL P DECOMP CONTINUE TO POOH WITH 2 -7/8" EUE 8 RD TUBING RACKING BACK IN DERRICK. -POOH FROM 9,498' TO 7776' -LAYED DOWN 4 STANDS OF PIPE DUE TO CROSS - THREADING, FLAGGED BAD JOINTS - MAINTAIN CONTINUOUS HOLE FILL AT 20 BPH LOSS RATE. Printed 8/30/2011 10:36:33AM *rth America - ALASKA - BP Page 7 oil 1 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2011 End Date: X4- 00V3F -E: (2,250,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/9/1997 12:00:00AM Rig Release: 8/1/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292272900 Active Datum: 22 : 33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 00:00 4.00 PULL P DECOMP HEAT TRACE TERMINATED AND SPOOL REMOVED FROM SPOOLER. -70K PUW - 540 -5' CLAMPS RECOVERED -SWAP ESP CABLE REELS AT SPLICE - MAINTAIN CONTINUOUS HOLE FILL AT 20 BPH LOSS RATE. 7/29/2011 00:00 - 04:00 4.00 PULL P DECOMP CONTINUE TO POH WITH 2 -7/8" 8RD EUE TUBING FROM 7776' TO ESP MOTOR. - MAINTAIN LOSS RATE OF 18 BPH. -LAY DOWN JOINTS 166, 167, 168 - 169, 170, 171 - 223, 224, 225 - 234, 235, 236 AS CROSS THREADED CONNECTIONS. THESE JOINTS WHERE LOCATED AT THE DEPTHS OF 3,731' THRU 3,638', 4,046' THRU 4,142' AND 5,812' THRU 6,002' WHILE COMPLETED. 04:00 - 07:00 3.00 PULL P DECOMP BREAK AND LAY DOWN ESP MOTOR ASSEMBLY - RECOVERED 540 HEAT TRACE CLAMPS, 285 CROSS - COLLAR CLAMPS AND 4 MOTOR CLAMPS 07:00 - 08:30 1.50 PULL P DECOMP CLEAR RIG FLOOR OF TOOLS AND EQUIPMENT. -CLEAN RIG FLOOR. - MAINTAIN CONTINUOUS HOLE FILL OF 18 BPH LOSS RATE. 08:30 - 10:00 1.50 CLEAN P DECOMP PJSM FOR M/U BHA. DISCUSS NON SHEARABLE WHILE RIH. -M /U BHA WITH MILL, SCRAPER, BOOT BASKETS, BIT SUB, BUMPER SUB, DRILL COLLARS XO TO 2 -7/8" TUBING. - RIH TO 215.07' WITH BHA. 10:00 - 15:00 5.00 CLEAN P DECOMP RIH WITH SCRAPER ON 2 -7/8" 8RD EUE FROM DERRICK FROM 215' TO 9643' - SCRAPE PACKER SETTING DEPTHS 3 TIMES FROM 9580 -9643' AND 8920 -9264' -120K PUW AND 75K SOW 15:00 - 18:30 3.50 CLEAN P DECOMP CIRCULATE 20 BBL HI-VIS SWEEP, 7 BPM AT 1950 PSI - DYNAMIC LOSS RATE 18 BPH - STATIC LOSS RATE 12 BPH -SPR 30 SPM @ 290 PSI, 40 SPM @ 620 PSI -AAR WITH CHECK 6 ON PUMPING SWEEP 18:30 - 20:00 1.50 CLEAN P DECOMP PJSM - CUT AND SLIP DRILLING LINE. 20:00 - 22:00 2.00 CLEAN P DECOMP PJSM POH -POH FROM 9,643' LAYING DOWN 2 -7/8" 8RD TUBING. 22:00 - 22:30 0.50 CLEAN P DECOMP KICK WHILE TRIPPING DRILL WITH AAR -GOOD DRILL, NEW CREW KNOWS RESPONSIBILITIES 22:30 - 00:00 1.50 CLEAN P DECOMP CONTINUE POH LAYING DOWN 2 -7/8" TUBING TO 6,655' - LOSSES AT 12 BPH WHILE POH. 7/30/2011 00:00 - 03:00 3.00 CLEAN P DECOMP POH FROM 6,655'TO 3,300'. - LOSSES AT 16 BPH 03:00 - 04:00 1.00 CLEAN P DECOMP RIH HOLE 13 STANDS OF 2 -7/8" TUBING FROM DERRICK. -POH UD 2 -7/8" TUBING. Printed 8/30/2011 10:36:33AM •rth America - ALASKA - BP Page 8 of 11 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2011 End Date: X4- 00V3F -E: (2,250,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/9/1997 12:00:00AM Rig Release: 8/1/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292272900 Active Datum: 22 : 33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 04:30 0.50 CLEAN P DECOMP KICK WHILE TRIPPING DRILL WITH MOTORMAN ON BREAK. -ALL HANDS REPORTED IN AND FULFILLED RESPONSIBILITIES. - LOADER OPERATOR NOTIFIED 3RD PARTY PERSONEL. 04:30 - 08:00 3.50 CLEAN P DECOMP POH FROM 3,300' WITH 2 -7/8" TUBING LAYING DOWN PIPE. - CONTINUOUS HOLE FILL AT 16 BPH LOSS RATE. - MONITOR WELL. STATIC. 08:00 - 09:00 1.00 CLEAN P DECOMP PJSM FOR UD BHA. -UD DRILL COLLARS, BUMPER SUB, SCRAPER, MILL. 09:00 - 10:00 1.00 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR. 10:00 - 12:00 2.00 EVAL P DECOMP PJSM. -R/U E -LINE AND USIT LOGGING TOOLS.,_ -RIH WITH LOGGING TOOLS. 12:00 - 13:00 1.00 EVAL P DECOMP RIH WITH LOGGING TOOLS. -RIH TO 9,000' AND FOUND FLUID WEIGHT DISCREPENCY POOH TO INSPECT EQUIPMENT. 13:00 - 14:00 1.00 EVAL P DECOMP POOH WITH E -LINE. -CLEAN AND INSPECT TOOLS. -RIH WITH ELINE 14:00 - 16:00 2.00 EVAL P DECOMP RIH WITH ELINE TO 9,000' 16:00 - 21:00 5.00 EVAL P DECOMP POH LOGGING FROM 9,000' TO SURFACE AT 2 5O MIN - REPEAT PASS NEEDED OVER INTERVALS SHOWING CORROSION - LOSSES 10 BPH 21:00 - 00:00 3.00 EVAL P DECOMP RIH TO REPEAT PASS OVER 7200' - 6500', 1700'- 1600', 1300'- 1100', 950' -850'. -HIGH RESOLUTION RUNNING SPEED IS 400' /HR 7/31/2011 00:00 - 01:00 1.00 EVAL P DECOMP POH WITH E -LINE FROM 1,000' TO SURFACE. 01:00 - 02:00 1.00 EVAL P DECOMP PJSM ON RIGGING DOWN E -LINE. -RIG DOWN E -LINE TOOL STRING AND EQUIPMENT. 02:00 - 04:00 2.00 RUNCOM P RUNCMP PJSM AND RIG UP TUBING RUNNING EQUIPMENT: 4 -1/2" UHT POWER TONGS, COMPENSATOR, 3 -1/2" ELEVATORS, CHANGE TO LONG BAILS. 04:00 - 08:00 4.00 RUNCOM P RUNCMP PJSM FOR RUNNING COMPLETION WITH HES, DOYON CASING, WSL AND RIG CREW -RIH 3 -1/2" 9.2# 13 Cr VAM TOP TUBING. -WLEG, XN NIP, JOINT A, X NIP, 7" X 3 -1/2" ?vv +" HES TNT PACKER, X NIP, TUBING, 3 -1/2" HES A. XD DURO SLIDING SLEEVE, TUBING, 7" X ^ 1 3 -1/2" HES TNT PACKER, 4-1/2" X 3 -1/2" XO, X C� NIP, 4 -1/2" HES XD DURO SLIDING SLEEVE. -RIH WITH 36 JOINTS OF 4 -1/2" 12.6# 13 Cr VAM TOP TUBING TO 2203'. Printed 8/30/2011 10:36:33AM 1110 rth America - ALASKA - BP Page 9 of 11 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2011 End Date: X4- 00V3F -E: (2,250,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/9/1997 12:00:00AM Rig Release: 8/1/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292272900 Active Datum• 22 : 33 3/25/199 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 10:00 2.00 RUNCOM X WAIT RUNCMP SHUT DOWN OPERATIONS. - AWAITING APPROVAL FROM BP TOWN FOR COMPLETION REDESIGN. -SPOKE WITH MP WELLS OPERATIONS SUPERVISOR, SUPERINTENDENT, TOWN ENGINEER. - RECEIVED APPROVAL ORDERED EQUIPMENT OUT. - MAINTAIN CONTINUOUS HOLE FILL AT 10 BPH LOSS RATE. - UNANNOUNCED WELL CONTROL DRILL. ALL HANDS REACTED ACCORDINGLY. HELD AAR WITH CREW, WSL, AND TOOL PUSHER. 10:00 - 12:00 2.00 RUNCOM P RUNCMP CONTINUE OPERATIONS -RIH WITH 4 -1/2" 12.6# 13 Cr VAM TOP TUBING FROM 2203' TO 3,880'. - MAINTAIN CONTINUOUS HOLE FILL AT 10 BPH LOSS RATE. 12:00 - 17:30 5.50 RUNCOM P RUNCMP CONTINUE RIH. -RIH WITH 4 -1/2" 12.6# 13 Cr VAM TOP TUBING FROM 3,880' TO 7,485'. -RIH WITH 4 -1/2" KBG2 GLM ASS WITH SHEAR OUT VALVE. - MAINTAIN CONTINUOUS HOLE FILL AT 10 BPH LOSS RATE. 17:30 - 18:00 0.50 RUNCOM P RUNCMP DISCUSS HOW A GLM AND DCR SHEAR OUT VALVE WORK WITH HES HAND AND RIG CREW. -SHUT DOWN FOR LUNCH. - MAINTAIN CONTINUOUS HOLE FILL AT 10 BPH LOSS RATE. 18:00 - 21:00 3.00 RUNCOM P RUNCMP CONTINUE RIH. RIH WITH 4 -1/2" 12.6# 13 Cr VAM TOP TUBING FROM 7,519" TO SURFACE. -AT SURFACE PUW 142K, SOW 107K - MAINTAIN CONTINUOUS HOLE FILL AT 10 BPH LOSS RATE. 21:00 - 22:00 1.00 RUNCOM P RUNCMP PJSM WITH FMC, MI, TRUCK DRIVERS AND RIG CREW TO LAND HANGER AND REVERSE IN CORROSION INHIBITOR -PU /MU LANDING JOINT - CONFIRMED LOCKDOWNS BACKED OUT -BLOW DOWN STACK -LAND HANGER AT 109K SOW -RILDS - BACKOUT AND LAYDOWN LANDING JOINT 22:00 - 00:00 2.00 RUNCOM P RUNCMP REVERSE CIRCULATE 150 BBLS OF SEAWATER - FOLLOW WITH 190 BBLS OF INHIBITED SEAWATER DOWN BACKSIDE 8/1/2011 00:00 - 00:30 0.50 RUNCOM P RUNCMP PU LANDING JOINT TO DROP BALL & ROD -DROP 1- 5/16" BALL & ROD Printed 8/30/2011 10:36:33AM • girth America - ALASKA - BP Page 10 of 11 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2011 End Date: X4- 00V3F -E: (2,250,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/9/1997 12:00:00AM Rig Release: 8/1/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292272900 Active Datum: 22 : 33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:30 - 02:00 1.50 RUNCOM P RUNCMP SET PACKERS AND TEST TUBING -250 PSI LOW FOR 5 MIN -3500 PSI HIGH FOR 30 MIN INITIAL PRESSURE: 3530 PSI AFTER 15 MIN: 3500 PSI AFTER 30 MIN: 3500 PSI IAOPSI -BLEED TUBING TO 1500 PSI -MIT IA LOW 250 PSI FOR 5 MIN -3800 PSI HIGH TEST ON IA FOR 30 MIN INITIAL PRESSURE: 3600 PSI AFTER 15 MIN: 3595 PSI AFTER 30 MIN: 3595 PSI TUBING 1500 PSI -02:00 CALLED WTL TO REVIEW TEST RESULTS, PERMISSION TO PROCEED WITH WELL PLAN 02:00 - 02:30 0.50 RUNCOM P RUNCMP BLEED DOWN TUBING TO SHEER DCK VALVE AT 2200' - CONFIRM VALVE SHEER BY PUMPING 2.5 BPM AT 870 PSI DOWN IA UP TUBING FOR A TOTAL OF 5.5 BBLS PUMPED -PUMP DOWN TUBING TAKING RETURNS UP IA AT 680 PSI 2.5 BPM FOR A TOTAL OF 4 BBLS PUMPED 02:30 - 04:00 1.50 WHSUR P RUNCMP FMC SET AND TEST TWC -250 PSI LOW AND 3500 PSI HIGH FOR 10 CHARTED MIN FROM ABOVE -1000 PSI FOR 10 CHARTED MIN FROM BELOW 04:00 - 05:00 1.00 WHSUR P RUNCMP PJSM FOR NIPPLE DOWN BOPE -NIPPI F OWN RDPF 05:00 - 05:30 0.50 WHSUR P RUNCMP H2S RIG EVAC DRILL WITH MAN DOWN AT CREW CHANGE -AAR AFTER MUSTER, MAN MISSING, SITE CONTROL SPECIALIST ROLE DURING DRILL DISCUSSED, ALL PEOPLE ENTERING AND EXITING THE PAD NEED A HARMONY SO SCS CAN ALERT THEM OF EVACUATION, DISCUSSED ROLE OF EMERGENCY SERVICES WITH MAN DOWN. 05:30 - 07:00 1.50 WHSUR P RUNCMP CONTINUE NIPPLING DOWN BOPE 07:00 - 10:00 3.00 WHSUR P RUNCMP NU 11" X 4- 1/16" ADAPTOR FLANGE AND 4- 1/16" 5K TREE -TEST TUBING HANGER VOID TO 5000 PSI FOR 30 CHARTED MIN -FILL AND TEST TREE TO 250 PSI LOW, 5000 PSI HIGH FOR 5 CHARTED MIN - CONFIRMED ALL TREE VALVES CLOSED 10:00 - 11:00 1.00 WHSUR P RUNCMP BAD THREADS ON 4" WING VAVLE WHITEY VALVE ON TREE -ND FLANGE AND REPLACE WITH NEW FLANGE X 1502 -TEST FLANGE TO 250 PSI LOW, 5000 PSI HIGH FOR 5 CHARTED MIN 11:00 - 12:00 1.00 WHSUR P RUNCMP RU DSM LUBRICATOR AND PRESSURE TEST TO 250 PSI LOW, 3000 PSI HIGH FOR 5 CHARTED MIN -PULL TWC Printed 8/30/2011 10:36:33AM • rth America - ALASKA - BP Page 11 of 11 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 7/20/2011 End Date: X4- 00V3F -E: (2,250,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/9/1997 12:00:00AM Rig Release: 8/1/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292272900 Active Datum: 22 : 33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 14:30 2.50 WHSUR P RUNCMP PJSM -RU LITTLE RED SERVICES TO FREEZE PROTECT IA AND TUBING DOWN TO SHFFR VALVE AT 2205' -PUMP 75 BBLS OF DEISEL AT 2 BPM @ 800 PSI -BLOW DOWN CIRCULATING LINES -RELEASE LRS 14:30 - 16:30 2.00 WHSUR P RUNCMP RU DSM LUBRICATOR - PRESSURE TEST LUBRICATOR TO 250 PSI LOW AND 3000 PSI HIGH FOR 5 CHARTED MIN -SET BPV -TEST BPV FROM BELOW TO 1000 PSI FOR 5 CHARTED MIN -RD LUBRICATOR 16:30 - 18:00 1.50 RIGD P POST BLOW DOWN AND RIG DOWN LINES, REMOVE SLOP TANK - SECURE TREE AND CELLAR. MOVE RIG MATS TO PREP FOR RIG MOVE AROUND BACKSIDE OF MPK PAD TO K -30. 24 HOUR NOTICE TO AOGCC INSPECTOR JOHN CRISP FOR INITIAL BOPE TEST ON MPK -30 -CRISP IS PLANNING TO WITNESS TEST, CALL WITH UPDATE TOMORROW AT 0600 **RIG RELEASED AT 1800** Printed 8/30/2011 10:36:33AM STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI N REPOR OF SUNDRY WELL OPERAONS 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Re -Open Sag River Perfs 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory ftb 196 -202 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 - 50 - 029 - 22729 - 00 - 00 7. Property Designation: j 8. Well Name and Number: ADL 375133 & 375132 * MPK - 33 9. Field / Pool(s): r 6 I rw Milne Point Unit/ Kuparuk River'Stn� 't L l 5 d 10. Present well condition summary Total depth: measured 11543 feet Plugs (measured) None true vertical 9310 feet Junk (measured) None Effective depth: measured 11483 feet Packer: measured None feet true vertical 9251 feet true vertical None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 112' 112' Surface 6630' 9 -5/8" 6666' 4948' 5750 3090 Intermediate Production 11492' 7" 11526' 9293' 7240 5410 Liner %4 DEC 7 ZU Perforation Depth: Measured Depth: 11374'- 11394' True Vertical Depth: 9142'- 9162' Tubing (size, grade, measured and true vertical depth): 2 - 7/8 ", 6.5# L - 80 11322' MD 9091' TVD Packers and SSSV (type, measured and true vertical depth):"°' " None 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure:ffd��� Perfs from 9280' 9334' were squeezed and tested to 500 psi. Well cleaned out to 11,475'. New perfs from 11,374' 11,394'. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1 0 0 Subsequent to operation: 0 0 0 1 1720 0 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: • Daily Report of Well Operations ® Development ❑ Service ❑ Exploratory ❑ Stratigraphic • Well Schematic Diagram 15. Well Status d m oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ Suspended after work: ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Hank Baca, 564 -5444 310 -212 Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name /Number. Sighature 1 _ - Phone 564 -4750 Date Sondra Stewman, 564 -4750 Form 10-404 Revised 07/2009 IMMS NOV O 5 , /( lO l oklhp my TREE: 2- 9/16" - 5M Cooper Orig. KB = 61.8 (N27E) WELLHEAD: 11 "x 7- 1/16" 5M FMC Gen. M P K -33 Orig. GL. = 27.8 (N27E) w/ 7 "x 2 -7/8" FMC Hanger w/ 3" LH Acme Orig. KB to BF = 19.8 (NOES) Top, 2.5" CIW H BPV profile Conductor Casing 112' Camco 2 -7/8" x 1" 171' KBMG -M -2 GLM Centrilift Heat trace 3228` 9 5/8" 40 ppf L -80 casing 6666' KOP @ 380' Max Hole Angle: 58° @ 3840' MD Angle thru perfs = 7° 3/8" Capillary Tube Max DLS = 4.34° @ 7311' MD 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg. ( drift ID = 2.347 ", cap. = 0.00592 bpf ) 7" 26 ppf, L -80, Btrc. prod. casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ) ( cap. of IA w/ tbg inside = 0.02758 bpf) Camco 2 -7/8" x 1" 11095` sidepocket KBMM -2 GLM Stimulation Summary 2 -7/8" XN nipple (ID 2.250 ") 11248` Perforation Summary Pump, 118 -G12 PMSSD 11270` Ref log: GR/CCL 01/29/97 _- Size SPF Interval (TVD) Gas Separator 4.5" 5 9280- 9306 7088' -7095' GRSFTX H6 11291 ` 3 3/8" ' -7105' Intake 11291' MD = 9060' TVD 3 3/8 " 4 9328-9334 7117' -7123' Tandem Seal Section 11296` GS63DBUT /LT 'shot 6/27/01 w/ Schlumberger Powerjet guns 15 bbls, 75 sx "G" 15.8# cement Motor, 76 HP, 1360 volt, 11310` 34 amp, Model KMH Sag River Perforations: ( Pheonix XTO w/6 fin 11318' Size PF Interval JTVD) centralizer Intake 11318' MD = 9087' TVD 45' 6 11374'- 11394' 9143' -9162' 7" float collar (PBTD) 11483' 7" 26 ppf L -80 BTRS 11525' DATE REV. BY COMMENTS 02/13/97 Moo ESP Completion 4 -ES MILNE POINT UNIT 02/24/98 M. Linder WELL K -33 04102/99 JWS Conversion from Sad River to Kuparuk 4ES API NO: 50 -029 -22729 06/29/01 B. Hasebe RWO Nabors 4ES Lee Hulme RWO Nabors 4-ES 08/09/08 Lee Hulme RWO Nabors 3S BP EXPLORATION (AK) 09/14/10 J. Perl RWO Nabors 4 -ES MPK -33 Well History Date Summary 06/23/10 ** *WELL S/I ON ARRIVAL" *'(rig prep) PULLED 1" BK -DGLV FROM ST #1 @ 8,924' MD. « « »» PULLED 1" BEK -DPSOV FROM ST #2 @ 88' MD. SET 1" BK -DGLV IN ST #2 @ 88' MD. WELL S/I ON DEP, NOTIFIED DSO. ** *JOB COMPLETE * ** 08/06/10 T /I /O = 200/300/0, PPPOT -T (pass) Tested to 5000 psi f /30 min lost 50 psi in 30 min LDS all functioned & torqued @ 350 ft Vs. PPPOT -IC (pass) Tested @ 3500 psi for 30 min w /no pressure loss. 08/06/10 * ** WELL S/I ON ARRIVAL * ** (sbhps) RAN 1.75" CENT,S.S & DUAL SPARTEK GAUGES.MADE 15 MINUTE STOP @ 8549' MD & THREE HOUR STOP @ 9078' MD. * ** CONTINUE ON 08 -07 -10 * ** 08/07/10 * ** CONTINUED FROM 08 -06 -10 * ** (sbhps) RAN 1.75" CENT,S.S & DUAL SPARTEK GAUGES.MADE 15 MINUTE STOP @ 8549' MD & 3 HOUR STOP @ 9078' MD. ASSISTED SUPPORT TECHS INSTALL BPV. » »BPV SET «« * ** * ** WELL S/I ON DEPARTURE 08/07/10 MPU Well ST demobed the flowlines and foundation „ NOTE BPV was set night before with Slick line. Also the 2nd IA valve was installed for RWO all IA and OA jewelry was removed and rig jewelry installed 08/14/10 Load & Transport Diesel 08/16/10 The Well Support Techs rigged up and set the foundation, flowlines and the wellhouse, They had to skew the tree so the BPV was pulled and a two -way check set. They then pressure tested the tree to 5000 psi and the flowlines to 1150 psi. The two -way check was then pulled. » » »» »NOTE: The BPV and TWC were left OUT and the leak tests were GOOD. 09/19/10 T /1 /0= 0/0/0. (Post RWO) Freeze Protect. Pumped 15 bbls crude down the Tbg. Pump 65 bbls crude down IA. FWHP= 0/420/0. Swab, Wing, Ssv closed. Mst., IA, OA open. NOVP 09/23/10 MPU Well ST PT'd flow lines test and production to 1150 psi for 10min with diesel. Passed. « « »> from well boar, also tubbing on IA and OA was installed and the 2nd IA valve was removed. 09/25/10 ** *WELL S/I ON ARRIVAL * * *(esp troubleshoot) RAN 1.5" LIB, TAG TOP OF ESP @ 11,256' SLM (11,270' MD) -14' ft correction. RAN 1.25" LIB, TAG ST #2 @ 171' MD. REC IMP OF BEK LATCH. RAN 2 -1/2" CAT VALVE, SD SOLID @ 326' SLM. RAN 3'x 1 -1/2" STEM, 2.29" G. RING TO 360' SLM, NO RESTRICTION. RAN 3'x 1 -1/2" STEM, 2.34" G. RING TO XN NIPPLE @ 11248' MD. FOUND RESTRICTIONS @ 4943 AND 7906' SLM. RAN 2 -1/2" CAT VALVE, SD SOLID @ 326' SLM. RAN 2 -7/8" BRUSH, 2.34" GAUGE RING. WORKED 326' SLM FOR 20 MINS. Page 1 of 2 MPK -33 Well History Date Summary 09/26/10 * * *CONT'D FROM 09- 25- 10 * * *(esp troubleshoot) RAN 2 -7/8" BRUSH, 2.34" GAUGE RING. BRUSHED RESTRICTION @ 326' SLM. RAN 2 -1/2" GR (steel), 2 -1/2" CAT VALVE. SD @ 326' SLM BUT FELL THROUGH, SD @ 5319' SLM STICKY. (valve came back sheared) RAN 2 -7/8" BLB, 2.34" G. RING. FOUND RESTRICTIONS @ 326', 5319', 5420, 7308,7906 SLM. RAN KJ, 2 -1/2" GR (steel), 2 -1/2" CAT VALVE (2.30" NG). WRK THROUGH 326' SLM, COULD NOT GET PAST 5,319' SLM. RAN KJ, 2" JU (steel), W/ 2 -1/2" D &D HOLE FINDER. SET @ 11,209' SLM (11,223' MD). LRS PT TBG TO 1000 PSI. (passed). WAS MISSING ENTIRE RUBBER ELEMENT WHEN GOT OUT OF HOLE. RAN 2 -1/2" GR (steel pin), 2 -1/2" BAIT SUB, KJ, 2 -7/8" BRUSH, 1" SPEAR W/ BARBS. SLOWED DOWN @ 150' SLM. APPEARED TO BE PUSHING SOMETHING DOWN HOLE. NOTHING CAME BACK ON TOOLS. * * *CONT'D ON 09- 27 -10 * ** 09/26/10 T /I /O = 650/660/0. Assist Slickline. Pumped 7.3 bbls criesel down to psi Tbg up to 1000 psi. Monitored psi. Bled down to 700 psi. Slickline on well at time of LRS departure. 09/27/10 * * *CONT'D FROM 09- 26- 10 * * *(esp troubleshoot) RAN 2 -1/2" GR (steel), 2 -1/2" BAIT SUB, 2 -7/8" BRUSH, 1.9" 2 PRONG WIRE GRAB TO XN. (no rubber recovered). RAN 5'x 2" P. BAILER TO TOP OF ESP @ 11,270' MD. (recovered 8 pieces, 1 /8th of element). * ** CONTINUE ON 09 -28 -10 * ** * * ** *BOP pressure test witnessed by BP Rep O'Neal Coyne * * * * ** 09/28/10 * ** CONTINUED FROM 09 -28 -10 * ** (trouble shoot esp) MADE SEVERAL RUNS W/ 2" X 5' PUMP BAILER TO TOP OF ESP @ 11 270' MD. RECOVERED ABOUT HALF OF THE RUBBER ELEMENT. * ** WELL S/I ON DEPARTURE * ** 10/02/10 ASRC Test unit #5, divert well thru sep, flow for formation fluids, pulling parameter samples * *job in progress ** * *test header ** 10/03/10 ASRC Test unit #5, start to to test MPK -33, ESP shut down, RDMO * *job complete ** * *test header ** 10/07/10 * ** WELL S/I ON ARRIVAL * ** (d &t/sbhps) RAN 2.10" CENT,3' X 1.5" STEM,2.056" CENT,1.5" LIB,TAGGED ESP @ 11258' SLM. RECOVERED SHAFT IMPRESSION. RAN 2.10" CENT,S.S,DUAL SPARTEK GAUGES.MADE 30 MINUTE STOP @ 10522' SLM & 3 HOUR STOP @ 11027' SLM. LOGGED UP @ 60 FPM FROM 11258' SLM TO 4988' SLM. (11270' MD to 5000' MD) * ** WELL S/I ON DEPARTURE * ** Page 2 of 2 N106' Arlieica -ALASKA - BP Page of ©peration °Summary Common Well Name: MPK -33 AFE No Event Type: MOBILIZATION (MOB) Start Date: 8/30/2010 End Date: X4- OORF8 -E (75,000.00) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active Da tum. 22.3 3/25/1999 16.00 @46.80ft (above Mean Sea L evel) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/30/2010 00:00 - 03:00 3.00 MOB P PRE SCOPE & LOWER DERRICK - RIG DOWN ALL SURFACE LINES. - RIG DOWN BEAVER SLIDE. - CH2 PRE HAULING VARIOUS LOADS OVER TO MPK -33 1 - 04:00 1.00 MOB P PRE PJSM. - MEETING WITH PEAK RIG MOVERS. SEPERATE RIG MODULES, STAGE LOADS IN LINE READY TO MOVE 04:00 10:00 6.00 MOB P PRE WAITING ON RIG MATS & PLY WOOD TO SHOW UP FROM PRUDHOE - TOOL SERVICE DIDN'T HAVE ENOUGH PLY i WOOD OR MATS TO COVER THE K -PAD ENTRANCE ROAD. 10:00 - 16:00 6.00 MOB P PRE MOVING RIG FROM MPS -43 TO MPK -33 - RIG MATS & PLY WOOD USED ON THE ACESS ROADS. 16:00 - 22:00 6.00 MOB P PRE MIRU: - SPOTTING RIG ON MATS OVER THE WELL. SPOTTING ALL OTHER RIG COPONENTS - CONNECT ALL SUFACE LINES. RIG ACCEPTED AT 22:00 Printed 11/4/2010 12:23:55PM North'America - ALASKA - BP Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active D atum: 22 : 33 3/25/199 1 @46.80ft (above Me an Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/30/2010 10:00 - 00:00 14.00 KILLW P DECOMP WAITING ON KILL FLUIDS FROM PRUDHOE. HAVING TO GET 2% KCL FROM HOT WATER PLANT, HOT WATER PLANT IS BACKED UP CREW TAKING THIS TIME TO WATCH THE REMEMBER CHARLIE (HSE) VIDEO. 8/31/2010 00:00 - 02:00 2.00 KILLW P DECOMP WAITING FOR KILL WEIGHT FLUIDS FROM PRUDHOE = WELL SUPPORT ROMOVED BPV LUBRICATOR TESTED TO 2000 PSI FOR 5 MIN, CHARTED 02:00 - 04:00 2.00 KILLW P DECOMP PJSM: - MEETING WITH CH2 VAC DRIVERS AND CREWS FOR UPCOMING KILL OPERAIONS - TAKING ON FLUIDS: 2 VAC TRUCKS WITH 2% KCL, 8.4 PPG, 110 DEG F. -FINAL TESTS OF SURFACE LINES, LINES TESTED TO 3500 PSI. - OVERBOARD LINE TO TIGER TANK TESTED TO 500 PSI WITH AIR. 04:00 - 07:30 3.50 KILLW P DECOMP PJSM: WELL KILL OPERATIONS: - I.A. PRESSURE-200, TBG PRESSURE -220 PSI, O.A. PRESSURE -20 - BLEAD PRESSURE FROM BOTH - PUMPED 1.5 TIMES TBG VOL= 80 BBLS DOWN THE TUBING 2 -5 BPM @ 0 -40 PSI, WITH NO RETURNS. SHUT IN TO BULL HEAD 1.5 TIMES THE WELLBORE VOL =450 BBLS - PUMPED MAX RATE OF 5 BPM, CAUGHT FLUID AFTER PUMPING 210 BBLS. - MAX PRESSURE ACHIEVED AT 5 BPM AFTER CATCHING FLUID WAS 300 PSI. 07:30 - 08:30 1.00 KILLW P DECOMP CONTINUE WELL KILL OPERATIONS: - STOPPED PUMPING. BOTH TBG AND IA WERE ON A STRONG VAC. j - ATTEMPTED TO DETERMINE A LOSS RATE. - PUMPED —100 BBLS AT 6 BPM AND WAS NOT ABLE TO CATCH FLUID. - FLUID LOSS RATE BASED ON THIS IS IN EXCESS OF 300 BBLS PER HOUR. RU AND PUMPED 125 BBL HI-VIS PILL DOWN THE TBG AT 5 BPM AND 1000 PSI. - NEVER SAW ANY RETURNS ON THE BACKSIDE. - CHASED PILL WITH 53 BBLS 2% KCL TO CLEAR TBG. - MONITORED WELL. STILL ON A STRONG VAC. Printed 11/4/2010 12:24:17PM If AC11@rIC� BP Page 2 of 2_ Aq Operation Summary Report AM Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Activ Datum: 22 : 33 3/2 5/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 12:00 3.50 KILLW P DECOMP RECIEVED WORD FROM RWO GROUP IN ANCHORAGE THAT WE WERE NOT GOING TO PROCEDE WITH THE WELL TILL WE COULD ESTABLISH A SOLID LOSS RATE. - WAITING ON PLAN FORWARD FROM RWO GROUP. -RIG CREW STILL PUMPING 20 BPH OF 8.4 - PPG 2% KCL IN THE I.A. OSHA MADE A VISIT TO THE RIG, ACCOMPANIED BY NABORS SAFETY REP 12:00 17:00 5.00 KILLW P DECOMP RIG ON STANDY BY FOR PLAN FORWARD FROM TOWN DECISION WAS MADE FROM TOWN THAT AN ATTEMPT WAS GOING TO BE MADE TO PLUG OFF THE PERFS WITH GEL MUD MIXED WITH AN LCM MATERIAL. 17:00 - 22:00 5.00 KILLW P DECOMP RECIEVED PLAN FORWARD FROM RWO ENGINEER -PLAN FORWARD WILL BE TO BULLHEAD 290 BBLS OF GEL MUD WITH CALCIUM CARBONATE IN AN ATTEMPT TO PLUG OFF THE PERFS. -RWO ENGINEER AND MI MUD ENGINEER WORKING TO PREPARE THE BLEND FOR THE PILL. -RIG CREW MAINTAINING 20 BPH HOLE FILL WITH 8.4 PPG 2% KCL. - WAITING FOR TRUCK WITH GEL MUD PILL FROM PRUDHOE 22:00 - 23:00 1.00 KILLW P DECOMP CALLED OUT WELLSUPPORT TO COME OUT AND PULL TWC - PUPMU & TEST LUBRICATOR TO 4500 PSI FOR 5 CHARTED MIN. - PULL TWC - LD LUBRICATOR - STAND BY FOR MUD PILL TRUCK. 23:00 00:00 1.00 KILLW P DECOMP PJSM WITH CREW TO DISCUSS THE GEL MUD PILL KILL OPERATION - PUMPED 290 BBLS OF GEL MUD PILL: -PILL WT -8.8 PPG @ 60 DEG F. - PUMPED 185 BBLS@ 3 -5 BPM @ 50 -180 PSI, BEFORE CATCHING FLUID. BULLHEADED 70 BBLS OF THE GEL MUD PILL @ 1.5 TO 5 BPM,180 -1850 PSI TO THE PERFORATIONS - DROPPED PUMP RATE FROM 5 BPM TO 1.5 PUMPED TOTAL OF 70 BBLS OF THE PILL INTO THE PERFS, FINAL PRESSURE OF 1850 PSI @ 1.5 BPM. Printed 11/4/2010 12:24:17PM AWd orth America - ALASKA - BP Rage 3 o Operation Summa dIrt Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active Dat um: 2 2 : 33 3/25/1999 16:00 @ 46.80ft (ab ove Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/1/2010 00:00 - 01:00 1.00 KILLW P DECOMP PJSM WITH CREW TO DISCUSS THE GEL MUD PILL KILL OPERATION - PUMPED 290 BBLS OF GEL MUD PILL: -PILL WT -8.8 PPG @ 60 DEG F. - PUMPED 185 BBLS@ 3 -5 BPM @ 50 -180 PSI, BEFORE CATCHING FLUID. BULLHEADED 70 BBLS OF THE GEL MUD PILL @ 1.5 TO 5 BPM,180 -1850 PSI TO THE PERFORATIONS - DROPPED PUMP RATE FROM 5 BPM TO 1.5 PUMPED TOTAL OF 70 BBLS OF THE PILL INTO THE PERFS, FINAL PRESSURE OF 1850 PSI @ 1.5 BPM. 01:00 - 04:00 3.00 KILLW P DECOMP - SHUT DOWN AND MONITORED WELL FOR ONE HOUR PRESSURE DROPPED FROM 1850 PSI TO O PSI IN 30 MIN. - BULLHEADED 18 BBLS INTO THE PERFS: PRESSURE ROSE TO 1600 PSI IN 6 BBLS. MAINTAINED 1600 -1760 PSI @ 1.5 BPM. I i OPENED THE TUBING UP THRU THE CHOKE TO THE GAS BUSTER TO ALLOW THE WELL TO BALLANCE IN ORDER TO ESTABLISH LOSS RATE. FILLED THE HOLE DOWN THE TUBING TAKING RETURNS UP THE ANNULUS THU THE CHOKE AND GAS BUSTER TO THE PITS. SHUT DOWN & MONITOR THE HOLE FOR HALF AN HOUR, ESTABLISHED LOSS RATE OF 6 BPH BULLHEADED 41 BBLS: BULLHEADED WITH 1.5 BPM @ 1450 TO 1700 PSI 104:00 - 05:00 1.00 KILLW P DECOMP SHUT IN AND MONITORED HOLE: - FILLED THE HOLE AFTER 30 MIN, TOOK 2.5 BBLS TO FILL LOSS RATE OF — 5 BPH. 05:00 - 07:00 2.00 KILLW P DECOMP SHUT IN & MONITOR - ON STAND BY FOR PLAN FORWARD FROM RWO GROUP 07:00 - 10:00 3.00 KILLW P DECOMP BULL HEAD THE LAST 172 BBLS OF GEL MUD PILL IN TO THE FORMATION -AT 5.1 BPM / —1700 PSI (3.5 BPM / - -1000 PSI. - PUMPS -OFF LET PRESSURE BLEED TO "0" PSI IN 55 MINUTES.(08:40 HRS) - MONITOR "OPEN' WELL TO ESTABLISH LOSS RATE. 16 BPH LOSS RATE AT 10:00 HRS. 110:00 - 12:30 2.50 WHSUR P DECOMP FMC REP INSTALLED TWC - TESTED TWC FROM ABOVE TO 4,500 PSI FOR 10 CHARTED MINUTES -GOOD TEST. - TESTED TWC FROM BELOW FOR 10 CHARTED MINUTES -WHILE INJECTING IN TO THE IA @ 1/2 TO 1/4 BPM (800 - 960 PSI) 3 BPH LOSS RATE AT 12:30 HRS. -BLEED OFF PRESSURE AND BLOW DOWN ALL LINES. Printed 11/4/2010 12:24:17PM orth'America- AL.ASKA� -�BP Page4�f�23 0' Operation Summary Report e c Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active Datum: 22 : 33 3/25/1999 16:00 @4 (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 - 14:00 1.50 WHSUR P DECOMP FMC REP BLEED OFF TBG HANGER VOID -PJSM -RD KILL LINES -ND 2 9/16" TREE AND ADAPTOR FLANGE. 114:00 00:00 10.00 BOPSUR P DECOMP PJSM -NU 7 1116" X 13 5/8" DSA -NU 1 3 5/8" (GK) 5M HYDRILL PSI BOP STACK WITH FOUR PREVENTER STACK UP. - HAVING TO JACK UP THE RIG TO GAIN THE HEIGHT FOR THE EXTRA VARIABLE RAM -(2 -3) BPH LOSS RATE AT 00:00 HRS. 9/2/2010 00:00 - 04:00 4.00 BOPSUR P DECOMP CONTINUE NU 13 -5/8" 5M, GK HYDRIL BOP W/ 4 PREVENTER STACK - RIGGING UP CHOKE LINE EXTENSION LINE - FUNCTION TESTING RAMS, - FILL STACK AIR OUT & PERFORM FULL BODY TEST. 04:00 - 06:00 2.00 BOPSUR P DECOMP INITIAL TEST OF 13 -5/8" 5M, GK HYDRILL BOP W/ 4 PREVENTER STACK TEST CHOKE MANIFOLD AND VALVES @ 250 / 4500 PSI. TEST TWO SETS OF 2 -7/8" x 5" VBR WITH 2 /Z 7/8" & 3 1/2" TEST JTS Il� 06:00 - 13:00 7.00 BOPSUR P DECOMP CONTINUE - INITIAL TEST OF 13 -5/8" 5M, GK HYDRILL BOP WITH 4 PREVENTER STACK PJSM - TEST BLINDS / SHEAR RAMS, CHOKE MANIFOLD VALVES, CHOKE AND KILL LINE VALVES, 250 / 4500 PSI. TEST BOTH, UPPER AND LOWER SETS OF 2 -7/8" x 5" VBR WITH 2 7/8" & 3 1/2" TEST JTS TEST 3 1/2" KELLY / UPPER & LOWER VALVES. - TEST FLOOR SAFETY VALVES, 2 7/8" AND 3 1/2" - TEST ANNULAR PREVENTER WITH 2 7/8" TEST JT, 250 / 3500 PSI - CHARTED ALL TEST FOR 5 MINUTES. - AOGCC WITNFS OFT ST WAIVFn RY JOHN CRISP 18:50 9/1/2010 - TEST WITNESSED BY BP WSL, NABOR'S TOOL PUSHER & NABORS DRILLER PERFORM KOOMEY DRAW DOWN TEST 200 PSI BUILD UP TO 1800 PSI FROM 1600 PSI = 46 SECONDS. FULL BUILD UP TO 3000 PSI = 190 SECONDS. 4 BOTTLES x 2050 PSI. 13:00 - 13:30 0.50 BOPSUR P DECOMP LD TEST JOINT, BLOW DOWN LINES AND VALVES -SET BACK KELLY 13:30 16:00 2.50 BOPSUR P DECOMP REMOVE AND RE- SILICONE ROTARY TABLE DRIP PAN UNDER THE RIG ROTARY TABLE. PAN WAS REMOVED TO PREVENT BEING DAMAGED - DURING NU OF THE ANNULAR PREVENTER BY LIFTING SLINGS. 16:00 16:30 0.50 BOPSUR P DECOMP PJSM NU DUTCH RISER SYSTEM. Printed 11/4/2010 12:24:17PM Irorth America - ALASf<� BP Page s o�23 Operation Summary Report N ` Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active Datum: 22: 33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 18:00 1.50 BOPSUR P DECOMP PJSM WITH WELL SUPPORT TECH. PU /MU AND TEST LUBRICATOR TO 3500 PSI - 5 CHARTED MINUTES, GOOD TEST. - PULL TWC WITH "0" PSI ON TBG. LD LUBRICATOR 18:00 19:30 1.50 WHSUR P DECOMP RD /LD DUTCH RISER SYSTEM. -PU LANDING JOINT WITH TIW VALVE AND 3" L.H. ACME XO. -PJSM: MU LJ TO TUBING HANGER, -FMC REP TO BACK OUT LOCK DOWN SCREWS. -PULL AND LD 2 -7/8" FMC TUBING HANGER 75K TO PULL FREE, 70 PUW - FILLED THE HOLE BEFORE PULLING HANGER, LOSS RATE STILL — 2 BPH. - CONFIRMED FLUID IS STILL UP TO THE ANNULAR IN THE BOP & THE LOSS RATE IS STILL — 2 BPH 1 19:30 - 22:30 3.00 WHSUR P DECOMP CIRCULATE BOTTOMS UP S - PUMPED A FULL BOTTOMS UP - 270 BBLS, PLUS 33 BBLS TO GET GOOD CLEAN 8.4 PPG 2% KCL IN AND OUT - PUMPED 2 -3 BPM @ 280 -530 PSI - SAW SOME OF THE GEL MUD PILL AT BOTTOMS UP, ISOLATED IT AND SHIPPED IT OUT TO THE TIGER TANK. 22:30 - 00:00 1.50 WHSUR P DECOMP PU PIPE HANDLING EQUIPMENT - PREPERATION FOR TOH. - RU ESP CABLE TO BE RUN THROUGH SHEIVE DOWN TO THE SPOOING UNIT. 9/3/2010 00:00 - 06:00 6.00 PULL P DECOMP TOH W/ 2 -7/8" 6.5#,L-80 EUE TUBING -POH RACKING BACK IN THE DERRICK - ATTACH ESP CABLE TO SPOOLER - MONITORING TRIP SHEET & KEEPING ACCURATE STRAP OF FLUIDS. AVG LOSS RATE STILL @ —2 -3 BPH -55 STANDS OUT AT 06:00 HRS. KICK WHILE DRILLING DRILL: - DRILLER CALLED THE DRILL, ALL CREW MEMBERS RESPONDED SAFELY AND EFFICIENTLY WELL WAS SUCURED, A MOCK CUTTING OF THE ESP CABLE WAS PERFORMED. AAR: - IT WAS NOTED THAT THE DRILLER DID NOT CALL OUT THE DRILL/ACTION OVER THE HARMONY, 06:00 08:30 2.50 PULL P DECOMP CONTINUE TO POH WITH 2 7/8" TBG ESP COMPLETION - 288 JOINTS - RECOVERED: 149 LASALLE CLAMPS, 3 FLAT GUARDS, 5 PROTECTOLIZERS. -FLOW CHECK. 2 -3 BPH LOSS RATE. Printed 11/4/2010 12:24:17PM orth America - ALASKA - BP Page 6 of 23 ,,. Operation Summary 'Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active Datum: 22: 33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 11:00 2.50 PULL P DECOMP PJSM -SNAKE ESP CABLE OVER SHEAVE IN DERRICK. -BO / LD ESP ASSEMBLY -NO SCALE NOTED -NO ESP DAMAGED NOTED. 11:00 12:00 1.00 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR. - REMOVE ESP SHIPPING BOXES FROM PIPE SHED. 12:00 - 13:30 1.50 PULL P DECOMP MU RUN TOOL FOR WEAR RING _ - SET WEAR RING WITH 6.125" I.D. 13:30 - 15:30 2.00 CLEAN P DECOMP PU A MU BHA # 1. CIBP MILLING BHA AS O i OWS -(3) 4 -3/4" BOOT BASKETS -(1) 6 -1/8" SPIRAL BLADE STRING MILL -(1) 7" CASING SCRAPER -(1) BIT SUB -(1) BUMPER SUB -(1) PUMP OUT SUB -(9) 4 -3/4" DRILL COLLARS 15:30 - 16:30 1.00 CLEAN N DECOMP ROTARY TABLE IS LOCKED UP -CREW IS HAVING TO GREASE THE TABLE TO GET IT TO TURN 16:30 - 17:00 0.50 CLEAN N DECOMP CONTINUE TO PU /MU BHA # 1 17:00 - 00:00 7.00 CLEAN N DECOMP RIH W/ MILLING BHA# 1 ON 3 -1/2" 15.5 # DP. - PICKING UP SINGLES FROM THE PIPE SHED 9/4/2010 i00:00 - 03:00 3.00 CLEAN P DECOMP RIH W/ MILLING BHA# 1 ON 3 -1/2" 15.5 # DP. - PICKING UP SINGLES FROM THE PIPE SHED -IN THE HOLE W/ 280 JNTS , -AVG LOSS RATE — 1 BPH H2S RIG EVACUATION DRILL: @ 00:30 -DRILL WAS CALLED BY THE DRILLER, CREW EVACUATED RIG WHILE AT THE SAME TIME MAKING SURE NO THIRD PARTY PERSONEL WERE ON LOCATION, CREW MUSTERED AT THE SAFE AREA (RIG CAMP) TOOL PUSHER GRABBED THE RIG PERSONEL ROSTER AND DID A CHECK OFF OF RIG PERSONEL, FORKLIFT DRIVER GRABBED THE SIGN IN ROSTER FROM THE SIGN IN SHACK TO VERIFY ALL PERSONEL ON LOCATION WERE ACCOUNTED FOR. AAR: DRILL WENT WELL, IT WAS CALLED OUT OVER BOTH RADIOS AND HEARD BY ALL PERSONEL ON THE RIG. 03:00 - 03:30 0.50 CLEAN P DECOMP STOPPED TO HAVE A PRE -JOB WITH THE CREW AND THE BAKER REP - DISCUSSED THE TAG UP DEPTH, POSSIBLE TRAPPED PRESSURES UNDER THE CIBP AND OUR MITIGATION PLAN FOR A POSSIBLE WELL CONTROL ACTION Printed 11/4/2010 12:24:17PM orth Arneric� �ALASKA - BP Page 7 of 23 -Operation Summary Report D " Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Ac tive Datum 2 2: 33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 04:00 0.50 CLEAN P DECOMP RIH W/ MILLING BHA# 1 ON 3 -1/2" 15.5 # DP. PICKING UP SINGLES FROM THE PIPE SHED RIH F/ JNT 280 A GED UP 28' IN ON JNT 290 ESTABLISH PARAMETERS: Z t� - 142 K PUW , 98 K SOW WITH OUT KELLY -145 K PUW , 102 K SOW WITH KELLY -ROT WT -188 K, OFF BOTTOM PSI - 830 PSI @ 3.5 BPM -240 AMPS OFF BOTTOM TORQUE -SPR: 1 BPM, 50 PSI 04:00 - 06:00 2.00 CLEAN P DECOMP START MILLING ON CIBP: - SET DOWN 3K AND DROPPED 4' AND TAGGED HARD AT 9,329', MUST HAVE TAGGED ON SOME JUNK. MILLING PLUG: - ROTATING AT- 70 RPM -WOB - 3K -270 AMPS ON BOT TORQUE - 830 -860 PP @ 3.5 BPM. 06:00 07:00 1.00 CLEAN P DECOMP CONTINUE MILLING ON CIBP: SPR =1 BPM / 60 PSI MILLING PLUG: F/9330 T/9331' MD ROTATING AT- 70 RPM -WOB - 3 -10K, PUW -145K, SOW -102K, RT WT -188K. -270 AMPS ON BOT TORQUE -3.5 BPM / 840 PSI -PU KELLY TO TOOL JOINT, PUMPS OFF, OBSERVED SLIGHT LOSSES, - SHUT -IN ANNULAR. 07:00 08:30 1.50 CLEAN P DECOMP PUMP 50 BBL GEL PILL (9.0 PPG) DOWN THE DP AND BULL HEAD -INTO FORMATION AT 2 BPM /1000 PSI, 3 BPW1600 PSI -3.5 BPM / 1850 PSI. PUMPS -OFF = 1000 PSI. -200 PSI DROP IN 15 MINUTES. BLEED TO'0' PSI, BLEED --2 BBLS BACK. -FLUSH DRILL STRING W/ 10 ADDITIOAL BBLS. - OBSERVED —1 BPH LOSS RATE. -SET BACK KELLY 08:30 09:00 0.50 CLEAN P DECOMP RIG SERVICE - MONITOR WELL, —1 BPH LOSS RATE. -PJSM PU DP FROM PIPE SHED. 09:00 - 11:00 2.00 CLEAN P DECOMP PU 3 1/2" DP FROM PIPE SHED AND PUSH PLUG -F/ 9331' MD T/ 10,648' MD Printed 11/4/2010 12:24:17PM orth ' erica - ALASKA - BP Page s of 23 .. ..' 1 ;. tat Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1, 125, 000. 00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Activ Datum 22: 33 3/25/ 16:0 @46.80ft (abo Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 12:30 1.50 CLEAN P DECOMP PU KELLY AND MILL AT 10,648' MD - ROTATING AT- 60 -80 RPM -WOB - 3 -1 OK, PUW -179K, SOW -118K, RT WT -135K. - 270 -290 AMPS ON BOT TORQUE -3.5 BPM / 840 PSI I UNABLE TO MAKE PROGRESS - ASSEMBLY TORQUES UP AND HANGING UP WHEN THE STRING IS WORKED. - DISCUSS PLAN FORWARD WITH ADW RWO ENGINEER AND RWO SUPERINTENDENT. -WILL COMPLETE MILLING OF PLUGS LATER DURING THIS RWO -ALSO SAID TO CIRCULATE A BOTTOMS -UP, MONITOR WELL PRIOR TO POH. 12:30 16:00 3.50 CLEAN P DECOMP WHILE CBU (4 BPM /'1000 PSI) A SMALL AMOUNT OF GAS WAS OBSERVED AT THE BELL NIPPLE. -WSL INSTRUCTED THE CREW TO SHUT -IN WELL AND FINISH CBU THROUGH THE GAS BUSTER. NO PIT GAIN WAS TAKEN. NO SHUT -IN PRESSURE NOTED. -AFTER CIRCULATING BOTTOMS -UP THE WELL WAS OPENED WITH'O' PSI AND —6 BPH LOSS RATE. -14:00 HRS: DISCUSSED WITH RWO SUPERINTENDENT- CONTINUE WITH SECOND BOTTOMS -UP. WILL RETEST ANNULAR WITH 2 7/8" TEST JOINT THIS TRIP TO SURFACE. - CIRCULATE ADDITIONAL 60 BBLS TO BALANCE U -TUBE. - MONITOR WELL, 6 -10 BPH LOSS RATE. -15:00 HRS: - DISCUSS PLAN FORWARD WITH ADW RWO ENGINEER - TRACTION 2010 -IR- 3609045 16:00 21:30 5.50 CLEAN P DECOMP POH F/ 10,648' MD AND STAND 3 1/2" DP IN DERRICK -15K OVER PULL ON FIRST PASS WITH 7" CSG SCRAPER AT ^9320' MD. -NO OVER PULL NOTED ON NEXT (2) PASSES. - SCRAPED PAST 9,200' & 9,100' WITH NO RESTRICTION -USE CONTINUOUS HOLE FILL WITH — 5 BPH LOSS RATE. Printed 11/4/2010 12:24:17PM orth America - ALASKA - BP ' Page 9 of 23 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active Datu 22: 33 3/25/1999 16:00 @46.80 (above Mea Se a Lev Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:30 22:30 1.00 CLEAN P DECOMP CLEAN OUT JUNK BASKETS AND LD THE REST OF THE BHA WHEN THE BIT REACHED SURFACE IT WAS NOTED THAT TWO OF THE CONES WERE COMPLETLY MISSING AND MOST OF THE TEETH FROM THE THIRD. THE THREE JUNK BASKETS CONTAINED 2 -1/2" GAL OF MATERIAL, 1 GAL BEING ALL METAL. TEETH AND OTHER PARTS OF THE BIT WERE FOUND IN THE BASKETS, NO EVIDENCE OF THE CONES WERE FOUND. - DISCUSSED THE SITUATION WITH THE DAY COMPANY MAN & CALLED THE RWO ENGINEER TO LET HIM KNOW AS WELL. IT WAS DECIDED THAT THE BEST OPTION WOULD BE TO CONTINUE WITH THE ORIGINAL PLAN OF DOING A CEMENT SQUEEZE. AND WE WOULD RUN A JUNK MILL AND POSSIBLY A REVERSE CIRC JUNK BASKET LATER. 1 1 22:30 - 23:00 0.50 CLEAN P DECOMP PULL & LD WEAR BUSHING -PREP TOOLS FOR RE- TESTING OF THE ANNULAR PREVENTER. - CURRENT STATIC LOSS RATE — 3 BPH, MAINTAIN CONTINUOUS HOLE FILL. p 23:00 - 00:00 1.00 BOPSUR P DECOMP SL 1 2 .718" .INT W/ Xn AND TEST PLUG TO P��1 TEST ANNUALAR PREVENTER. ` - TESTING TO 5�O PSI LOW AND 3500 PSI HIGH. - UNABLE TO GET TEST. 9/5/2010 00:00 02:00 2.00 BOPSUR P DECOMP SWITCHED OUT THE 2 -7/8" AND XO MADE UP TO TEST PLUG -PU AND RU A TEST JOINT, RE -TRY ANNULAR PREVENTER TESTS -TESTS STILL FAILING, DRAINED THE STACK AND LOOKED DOWN THE BOPE STACK AND COULD VISABLY SEE PIECES OF THE ANNULAR STICKING OUT. -NIGHT TOUR PUSHER INFORMED ME THAT THEY WERE GOING TO HAVE TO C/O THE RUBBER ELEMENT. - NOTIFIED THE DAY COMPANY MAN OF THE OPERATIONS. LOSS RATES AT 2 -3 BPH FILLING HOLE EVERY HOUR 02:00 - 06:00 4.00 BOPSUR N DECOMP PJSM: FOR ANNULAR RUBBER C/O DISCUSSION AROUND THE CHANGE OF SCOPE AND LIMITED SPACE WITH THE 4 PREVENTER STACK - JACK -UP SUB 4 " -6" - RIGGING DOWN THE DUTCH RISER SYSTEM & ANNULAR PREVENTER CAP 06:00 06:30 0.50 BOPSUR P DECOMP RIG SERVICE AND PERFORM PRE -TOUR CHECKS. Printed 11/4/2010 12:24:17PM orkh America.- ALASKA - BP Page _ 0 of 23, operation Summary RepoIrt Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active Datum 22: 33 3/25/19 16:00 @46 .80ft ( above Mea S e a Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 07:00 0.50 BOPSUR P DECOMP PJSM CHANGE -OUT 13 5/8" ANNULAR PREVENTER ELEMENT. - LIFTING AND RIGGING - DROPPED OBJECTS - INSPECTION OF TOOLS 07:00 13:30 6.50 BOPSUR N DECOMP REMOVE 13 5/8" ANNULAR PREVENTER ELEMENT - RECOVERED (2) LARGE PEACES OF RUBBER LAYING ON TOP OF BLIND RAMS. - INSTALL NEW ELEMENT AND ANNULAR CAP. -USED KELLY TO ASSIST IN DRAW -DOWN OF CAP. - JACK -DOWN SUB. NU. DUTCH SYSTEM FLANGE, BELL NIPPLE - FLOW LINE. -RU HANDRAILS. -SHIP 50 BBLS KWF FROM PITS TO VAC TRUCK, RINSE WITH OLD 9.0 GEL PILL AND SHIP TO TIGER TANK. 113:30 14:30 1.00 BOPSUR P DECOMP PU / MU 2 3/8" TEST JOINT AND RU TEST EQUIPMENT _TPRT 11 " ANbJULAR T0250 PSI/ 350C FOR 5 CHARTED MINUTES. GOOD TEST. -RD TEST EQUIPMENT. 14:30 - 15:30 1.00 BOPSUR P DECOMP HELD WEEKLY SAFETY MEETING WITH NABORS TOOLPUSHER. - TRAINING VIDEO (REMEMBER CHARLIE) -WSL HELD SAFETY MEETING WITH SUPPORT CREW IN THE SHOP -OPEN DISCUSSION: HAZARDS AND SAFE USE OF MANY DIFFERENT TOOLS, PPE, - WORKING WITH HELPERS, DROPPED OBJECTS, GOOD WORK HABITS,ETC. 115:30 - 17:00 1.50 BOPSUR P DECOMP PJSM WITH HES ON MU 7" HES BHA -PU BHA #2 FAST DRILL BRIDGE PLUG & CHAMP PACKER TO RIG FLOOR. - MW 7" COMPOSITE BRIDGE P LUG W/ PUP_ 17:00 - 22:00 5.00 DHB P DECOMP RIH WITH BHA # 2 ON 3 -1/2" 15.5 # DP FROM THE DERRICK -TIH TO 9,380' -LOST 14 BBLS FOR THE TRIP, — 2 -3 BPH LOSS RATE 22:00 - 23:30 1.50 DHB P DECOMP PJSM WITH HALLIBURTON FOR PACKER I SETTING OPERATIONS j - IN THE HOLE . 9,380' , DROPPED BALL - PUW 140 K, SOW 97 K -NU TIW & CIRCULATION PIN - CIRCULATING WTIH 1 BPM @ 60 -70 PSI -BALL ON SEAT PRESSURE LIP TO 2200 PSI TO SET FAST DRILL PLUG PU 22 K OVER TO SHEAR OFF. 23:30 - 00:00 0.50 DHB P DECOMP PU TO 9,351's -SET CHAMP PACKER -TOOK TWO TRIES TO SET Printed 11/4/2010 12:24:17PM ^ orth America - ALASKA - BP Page 1 1 of m. Qperation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active Datum: 22: 33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/6/2010 00:00 - 01:30 1.50 DHB P DECOMP RU TEST EQPT TO TEST FAST DRILL PLUG - BROUGHT PUMPS TO 2000 HELD FOR 10 MIN CHARTED ,( GOOD SOLID TEST) -UNSET CHAMP PACKER & ALLOW ELEMENTS TO RELAX _PU HOLE TO 2 R - ET CHAMP PACKER P ,` 101:30 - 02:00 0.50 DHB P DECOMP TEST THE T CASING PT TO 2000 PSI FOR 30 MIN CHARTED, GOOD TEST) 02:00 03:00 1.00 DHB DECOMP INITIAL INJECTIVITY TEST - PRESSURE TEST BELOW THE CHAMP PACKER 1/2 BPM , REACHED 930 PSI THEN BROKE_ O VER TO 400 PSI - PUMP RATE/ PRESSURE/ BBLS PUMPED 1 BPM /1050 PSI / 6 BBLS 1 -1/2 BPM / 1250 PSI / 5 BBLS ( 2 BPM / 1430 PSI / 7 BBLS y e 2 -1/2 / 1600 PSI / 8 BBLS 3 BPM / 1800 PSI / 9 BBLS rr SHUT DOWN, PRESSURE BLED OFF TO 930 PSI IN 2 MIN. -BLEED PRESSURE OFF - RELEASE PAKCER AND MONITOR WELL -WELL OUT OF BALANCE, SLIGHT FLOWING OUT THROUGH THE DP. 03:00 - 04:00 1.00 DHB P DECOMP CIRCULATED BOTTOMS UP -CIRC AT 4 BPM @ 1010 PSI -SHUT DOWN MONITOR WELL -BOTH SIDES ON A VAC 04:00 - 06:00 2.00 CLEAN P DECOMP TOH WITH (HES) CHAMP PACKER ON 3 -1/2" 15.5 # DP, STANDING BACK IN THE DERRICK - CURRENT LOSS RATE WHILE TRIPPING — 6 BPH 06:00 - 06:30 0.50 CLEAN P DECOMP RIG SERVICE. 06:30 - 07:00 0.50 CLEAN P DECOMP PERFORM PRE -TOUR CHECKS -PJSM, POH. 07:00 - 10:30 3.50 DHB P DECOMP CONTINUE TO POH WITH (HES) CHAMP PACKER ON 3 -1/2" 15.5 # DP, - STANDING BACK IN THE DERRICK -FROM STAND # 45 10:30 - 11:00 0.50 DHB P DECOMP PJSM. LAY DOWN (9) 4 3/4" DC'S -LD 7" RTTS _ 3 BPH LOSS RATE. 1 11:00 - 12:00 1.00 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR. 12:00 - 19:00 1 7.00 DHB P DECOMP MU HES 7" CAST IRON CEMENT RETAINER -RIH ON 3 1/2" DP FROM DERRICK. -TO 9100' MD, 19:00 - 19:30 0.50 DHB P DECOMP T AINER @ 2100' . -SET WITH 36 TURNS TO THE RIGHT, PU 30K OVER AND SHEAR OUT. -36 RIGHT HAND TURNS AGAIN TO OPEN THE 1 TOOL. I Printed 11/4/2010 12:24:17PM orth America - ALASKA - BP:,•Pageti Operation .Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active Datum: 22 : 33 3/25/19 16:00 @46.80ft (a bove Me an S ea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 20:30 1.00 DHB P DECOMP PRESSURE TEST THE CEMENT RETAINER -PT 1000 PSI FOR 30 MIN CHARTED. -GOOD TEST -BLEED PRESSURE AND STING BACK IN FOR THE INJECTIVITY TEST 20:30 21:30 1.00 DHB P DECOMP PERFORM SECOND INJECTIVITY TEST - PUMP RATE / PRESSURE/ BBLS PUMPED 1 BPM / 970 PSI / 6 BBLS 2 BPM / 1370 PSI / 6 BBLS 3 BPM / 1740 PSI / 6 BBLS 21:30 - 00:00 2.50 DHB P DECOMP PREPERATION FOR CEMENT SQUEEZE JOB SPOT TRUCKS AND EQUIPMENT RU SURFACE LINES - RIG UP ON THE OPEN TOP TANK FOR CEMENT RETURNS - HAD SOME TROUBLE WITH THE OPEN TOP TANK, HAD TO RECONFIGURE THE RIG UP. 9/7/2010 00:00 - 00:30 0.50 ZONISO P DECOMP P JSM FOR CEMENT SQUIrEEOPERATION CREW AND ALL THIRD PARTY ON LOCATION. - FINISH RIGGING UP LINES ON THE RIG FLOOR -AIR TEST LINES CEMENTERS TESTING SURFACE LINES TO 4500 PSI. 1 02:00 1.50 ZONISO P DECOMP CEMENT SQUEEZE JOB AS FOLLOWS - PUMPED 50 BBLS OF HEATED FRESH WATER, STING BACK INTO RETAINER AND PUMP TWO BBLS TO ENSURE THE RETAINER CAN BE PUMPED THROUGH BEFORE MIXING CEMENT. -STING INTO CEMENT RETAINER AND START PUMPING CEMENT -PUMP 50 BBLS OF 15.8 #, 1.16 FT3 /SK, 5.103 GAUSK, CLASS G CEMENT -PUMP 59 BBLS OF FRESH WATER DISPLACEMENT. SQUEEZED ALL 50 BBLS OF CEMENT AT 1/2 , B TO 2 BPM, W/ P RESSURES RANGING F/ 188 PSI TO A FINAL PRESSURE OF 1474 PSI. - 1.5 TO 2 BBL CEMENT LEFT ON TOP RETAINER. 02:00 02:30 0.50 ZONISO P DECOMP PICK UP OUT OF RETAINER - PU 40' - CLOSE ANNULAR PREVENTER AND REVERSE CIRCULATE - CIRCULATE AT 4 BPM TO 1000 PSI, TOTAL OF 70 BBLS. - MAKING SURE THE RETURNS ARE CLEAN 02:30 - 03:00 0.50 ZONISO P DECOMP P RESSURE TEST THE CEMENT RETAINER AND CEMENT - PT TO 1000 PS FO 30 CHARTED M IN. - GOOD TEST. - RIG UP TO POOH 03:00 - 06:00 3.00 ZONISO P DECOMP POOH WITH HES CEMENT STINGER ON 3 -1/2" 15.5 # DP, STANDING BACK IN THE DERRICK -50 STANDS OUT 06:00 - 06:30 0.50 ZONISO P DECOMP RIG SERVICE AND PERFORM PRE -TOUR CHECKS. Printed 11/4/2010 12:24:17PM orW America - ALASKA -'BP Page l_� 23 Qperation Summary : Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active Datum: 22 : 33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 - 09:00 2.50 ZONISO P DECOMP CONTINUE TO POH FROM STAND # 50 TO #95. -HOLE IS STATIC -LEFT MESSAGE ON NORTH SLOPE # 659 -3607 OF WEEKLY BOPE TEST ON MPK -33 0830 HRS 9/7/2010. 09:00 09:30 0.50 ZONISO P DECOMP PJSM - B/0 AND L/D SQUEEZE TOOL STINGER. 09:30 - 10:30 1.00 ZONISO P DECOMP CLEAN AND CLEAR RIG FLOOR. 10:30 12:00 1.50 ZONISO P DECOMP PJSM PU BHA TO RIG FLOOR -MU BHA #3 -PU (9) 4 3/4" DC'S FROM PIPE SHED. -6 1/8" BIT, (3) BOOT BASKETS, BS, BUMPER SUB, PUMP OUT SUB, (9) 4 3/4" DC'S = 303.49' 12:00 - 15:30 3.50 ZONISO P DECOMP RIH WITH BHA #3 ON 3 112" DP FROM DERRICK -TO —8600' MD, PUW = 136K, SOW = 83K. 15:30 - 16:00 0.50 ZONISO P DECOMP MU AND SET 7" STORM PACKER AT —91' MD -LD (3) JTS DP 16:00 - 16:30 0.50 ZONISO P DECOMP RU TEST EQUIPMENT AND TEST 7" STORM PACKER -500 PSI FOR 10 RECORDED MINUTES. GOOD TEST. 16:30 - 18:00 1.50 BOPSUR P DECOMP PJSM -ND BOPE -SUCK FLUID OUT OF BOP STACK. -LEFT MESSAGE ON NORTH SLOPE # 659 -3607 OF WEEKLY BOPE TEST ON MPK -33 @ 1800 HR 9/7/2010. 18:00 - 22:00 4.00 BOPSUR P DECOMP PTM. N/D (4) PREVENTOR STACK, REMOVE SINGLE GATE - STAND BACK REMAINDER OF BOP - N/D & REMOVE TUBING SPOOL -LEFT MESSAGE ON ANCHORAGE #907- 793 -1236 OF WEEKLY BOPE TEST ON MPK -33 @2010 HRS 9/7/2010. 22:00 - 00:00 2.00 WHSUR P DECOMP PJSM. INSTALL NEW PACKOFF. N/U FMC GEN 5 TUBING SPOOL. 9/8/2010 00:00 - 02:00 2.00 WHSUR P DECOMP CONTINUE TO N/U FMC GEN 5 TUBING SPOOL. RILDS, TEST SPOOL & PACKOFF @ 4500 PSI / 30 MIN / CHARTED, OK. 02:00 - 03:30 1.50 BOPSUR P DECOMP PJSM. N/U 13 5/8" X 5M BOPE. N/U SINGLE GATE ON TOP OF SPOOL N/U REMAINDER OF STACK 103:30 - 04:30 1.00 BOPSUR P DECOMP WEEKLY SAFETY MEETING. - REVIEW OF STOP CARDS AND RECENT INCIDENTS - REVIEW OF WELL CONTROL EXPECTATIONS W/ REGARD TO SUSPECTED INFLUXES EMPHASIS ON CONSTANT MONITORING OF WELL AND FLUIDS, (PITS)\ EMPHASIZE KEEPING ALL WELL CONTROL EQUIPMENT IN GOOD WORKING ORDER 04:30 06:00 1.50 BOPSUR P DECOMP CONTINUE TO N/U MUD CROSS VALVES ON BOP. Printed 11/4/2010 12:24:17PM orth America - ALASKA - SP Page 0 of € 2 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 A ctive Datum: 22:33 3/2 5/1999 16:0 @ 46.8 0 ft (above M ean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 06:30 0.50 BOPSUR P DECOMP RIG SERVICE AND PERFORM PRE -TOUR CHECKS. 06:30 - 07:00 0.50 BOPSUR P DECOMP PJSM -RU TEST EQUIPMENT -LEFT MESSAGE ON NORTH SLOPE # 659 -3607 OF WEEKLY BOPE TEST ON MPK -33 0750 HRS 9/8/2010. 07:00 - 15:00 8.00 BOPSUR P DECOMP BOP TEST: - FUNCTION TESTING RAMS, - FILL STACK & PERFORM FULL BODY TEST. WEEKLY TEST OF 13 -5/8" 5M, GK HYDRILL BOPE W/ 4 PREVENTER STACK - TEST CHOKE MANIFOLD AND VALVES @ 250 / 4500 PSI. - TEST TWO SETS OF 2 -7/8" x 5" VBR WITH 2 7/8" & 3 V2" TEST JTS TEST BLINDS /SHEAR RAMS, CHOKE MANIFOLD VALVES, CHOKE AND KILL LINE VALVES, 250 / 4500 PSI. - TEST BOTH, UPPER AND LOWER SETS OF 2 -7/8" x 5" VBR WITH 2 7/8" & 3 V2" TEST JTS - TEST 3 1/2" KELLY / UPPER & LOWER VALVES. TEST FLOOR SAFETY VALVES, 2 7/8" AND 3 1/2" - TEST ANNULAR PREVENTER WITH 2 7/8" TEST JT, 250 / 3500 PSI CHARTED ALL TEST FOR 5 MINUTES. AOGCC WITNESSING OF TEST WAIVED FROM ANCHORAGE BY JIM REGG, 10:00 9/8/2010 - TEST WITNESSED BY BP WSL, NABOR'S TOOL PUSHER & NABORS DRILLER - PERFORM KOOMEY DRAW DOWN TEST - 200 PSI BUILD UP TO 1800 PSI FROM 1600 PSI = 50 SECONDS. - FULL BUILD UP TO 3000 PSI = 187 SECONDS. 4 BOTTLES x 2070 PSI. 15:00 15:30 0.50 BOPSUR P DECOMP INSTALL 7" I.D. WEAR RING 15:30 16:30 1.00 DHB P DECOMP PU 3 JTS 3 112" DP - ENGAUGE 7" STORM PACKER 91' MD . -NO PRESSURE UNDER PACKER -ALLOW ELEMENT TO RELAX -LD 3 JTS 3 1/2" DP AND STORM PACKER. 16:30 - 19:00 2.50 CLEAN P DECOMP RIH F/ -8600' T/— 9050' -TAG CEMENT AT 9068' MD -KELLY UP. -PUW = 141 K, SOW = 100K, RT WT = 120K, 80 RPM, TORQUE = 7K. -SPR = 2 BPM / 190 PSI. 4 BPM / 930 PSI -DRILL CEMENT FROM 9068' MD TO CMT RETAINER @ —9100' MD 19:00 - 21:30 2.50 CLEAN P DECOMP MILL ON CEMENT RETAINER F/ 9100'- 9103'. WOB = 8 - 12K, 80 RPM, 4 V2 BPM @ 1025 PSI. 9500 FT /LBS TORQUE ,Printed 11/4/2010 12:24:17PM orth America -AL ASKA- BP 15 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active Datu 22: 33 3/25/1 16: @46.80ft (abo Me Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:30 00:00 2.50 CLEAN P DECOMP D RILL CEMENT F/ 9103' - 9168' - PUMP SWEEPS AS NECESSARY. - 30 FT / HR AVG ROP 9/9/2010 00:00 - 05:30 5.50 CLEAN P DECOMP CONTINUE TO DRILL CEMENT, MED / HARD F/ 9168'. - 80 RPM, 4 112 BPM @ 1035 PSI, 10 -12K WOB - ROTARY TORQUE = 9500 FT /LBS - AVG ROP = 30 - 40 FPH - 141 K UP WT, 100K DOWN WT, 115K ROTATING WT. - PUMPING 10 BBLS HI VIS SWEEPS EVERY 30' - DRILL CEMENT TO 9370'. - TOP PERFS, (SQUEEZED) @ 9280', NO LOSSES INCURRED W/ DRILLING. 05:30 - 06:00 0.50 CLEAN P DECOMP PJSM. PUMP 15 BBLS HI VIS SWEEP - CIRCULATE BOTTOMS UP, 4 V2 BPM @ 1035 PSI. 06:00 - 07:30 1.50 CLEAN P DECOMP CONTINUE TO CIRCULATE TILL RETURNS ARE CLEAN 07:30 - 10:30 3.00 CLEAN P DECOMP TEST TO CONFIRM CEMENT SQUEEZE y AT 9370' MD -PUMP 11 STK TO 500 PSI / FOR 30 CHARTED MINUTES, LOST -140 PSI IN 30 MIN. -PUMP 3 STK TO INCREASE TO 500 PSI -TEST, LOST -60 PSI IN 30 MINUTES -SEND TEST CHART TO ADW RWO ENGINEER -OK TO RESUME OPERATIONS. 10:30 - 11:30 1.00 CLEAN P DECOMP CONTINUE TO D-RILL_CE F/ 9370' MD . - AND COMPOSITE BRIDGE PLUG AT 9380'T 9382 MD. - 80 RPM, 4 1/2 BPM @ 1035 PSI, 10 -12K WOB ROTARY TORQUE = 9500 FT /LBS - AVG ROP = 30 - 40 FPH - 141 K UP WT, 100K DOWN WT, 115K ROTATING WT. 11:30 - 12:30 1.00 CLEAN P DECOMP -SET BACK KELLY -RIH FROM DERRICK F/ 9382' MD AND TAG FISH & CIBP LEFT AT 10,648' MD, W/ 1 O WOB. -PUSH DOWN TO 10,683' MD. UNABLE TO PUSH DOWN DEEPER. -P UW = 205K, SOW = 102K. 12:30 14:00 1.50 CLEAN P DECOMP CIRCULATE BOTTOMS UP 4.5 BPM / 1500 PSI. - MONITOR WELL 14:00 15:30 1.50 CLEAN P DECOMP POH F/ 10,683' MD. T/ 8780' MD -STAND 20 STANDS IN DERRICK. -FIRE DRILL IN PIPE SHED. 15:30 - 17:00 1.50 CLEAN P DECOMP PJSM- CUT AND SLIP DRILL LINE. 17:00 18:00 1.00 CLEAN P DECOMP POH F/ -8780' MD 18:00 18:30 0.50 CLEAN P DECOMP SERVICE RIG AND PERFORM PRE TOUR CHECKS 18:30 - 22:00 3.50 CLEAN P DECOMP CONTINUE TO POOH. STAND BACK 113 STDS 3 V2" DP - HOLE TAKING PROPER DISPLACEMENT, NO FLUID LOSS Printed 11/4/2010 12:24:17PM North America -"AL BP Page 16 ei Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 A ctive Da tum: 22 : 33 3/25/1999 16:00 @46.80ft ( abov e Mean Sea Lev Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 00:00 2.00 CLEAN P DECOMP PJSM. STAND BACK 4 3/4" DCS, L/D BHA - BIT IS WORN WITH SEVERAL TEETH BROKEN OFF (INNER) & SOME WEAR ON OUTER - BEARINGS ARE GOOD, BIT IS IN GAUGE - TWO GALLONS OF CMT IN JUNK SUBS ALONG WITH BRASS AND IRON. - CLEAR / CLEAN RIG FLOOR. 9/10/2010 00:00 01:30 1.50 CLEAN P DECOMP PJSM. P ICK UP MILLING BHA INCLUDING: - 5 BLADED JUNK MILL, (3) JUNK SUBS, BIT SUB - BUMPER SUB, OIL JARS, PUMP OUT SUB, (9) 4 3/4" DCS - OVERALL LENGTH = 315.91' 01:30 06:00 4.50 CLEAN P DECOMP RIH W/ MILLI BHA ON 3 1/2" DP BOP DRILL, (UNANNOUNCED), W/ RIH VERY GOOD RESPONSE BY CREW, WELL SECURED, 1 MIN 25 SEC - MONITOR WELL, VERY STABLE, CONTINUE IN HOLE 06:00 07:00 1.00 CLEAN P DECOMP A FISH AT 10.683' MD CIRCULATE "SAFE- SURF -O" SURFACE TO SURFACE _ -TO REDUCE TORQUE 07:00 - 12:30 5.50 CLEAN P DECOMP MILL ON RS H AN. p_CHASE TO BOTTOM. . -60 RPM, 8 -14K WOB, FR TQ = 9K. TQ = 1 OK -PUW 180K, SOW 112K, FR WT = 137K. -SPR 2 BPM / 380 PSI. -4 BPM/ 1030 PSI -MILL BRIDGE PLUG F/ 10,683' T/ 10,797' MD -SET BACK KELLY PU 3 1/2" DP FROM PIPE SHED AND TO 10.996% PU KELLY - UNABLE TO CIRCULATE - PUSH T/ 11016' MD WHILE ATTEMPTING TO REGAIN CIRCULATION. -BOP DRILL (INCREASE IN FLOW WHILE DRILLING) -GOOD RESPONSE BY DRILLER AND CREW, 1 MIN 50 SEC. 12:30 - 14:30 2.00 CLEAN N DPRB DECOMP UNABLE TO CIRCULATE - FUNCTION TESTED SURFACE EQUIPMENT -WORK AND SURGE DRILL STRING, FAILED TO REGAIN CIRCULATION. - DISCUSSED PLAN FORWARD WITH ADW RWO SUPERINTENDENT AND RWO ENGINEERS. -DROP BALL AND SHEAR THE PUMP -OUT SUB -1800 PSI. -NO ATTEMPT WAS MADE TO _ REV - CIRCULATE. 14:30 17:00 2.50 CLEAN P DECOMP CIRCULATE 40 BBLS FLO -VIS SWEEP SURFACE TO SURFACE. -5 BPM/ 1370 PSI - CIRCULATED 394 BBLS. -SPILL DRILL AT CUTTING BOX. 17:00 18:00 1.00 CLEAN P DECOMP PJSM. POOH W/ 3 1/2" DP & MILLING BHA. 18:00 18:30 0.50 CLEAN P DECOMP CONDUCT PRE TOUR CHECKS AND SERVICE EQUIPMENT Printed 11/4/2010 12:24:17PM o_rth America - ALASKA - BP Page 17 of 2- Operation Summary ; Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active Datum: 22: 33 3/2 5/1999 1 6:00 @46.80ft (abov Mea Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 23:00 4.50 CLEAN P DECOMP PJSM. CONTINUE TO POOH W/ 3 1/2" DP & MILLING ASSEMBLY 23:00 00:00 1.00 CLEAN P DECOMP PJSM. STAND BACK COLLARS, BREAK DOWN BHA. - PLUGGED W/ FIN METAL / CEMENT ALL THE WAY UP IN TO JAR - MILL SEVERELY WORN ON FACE AND SIDES - UN PLUG BHA AND EMPTY JUNK SUBS - CONFER W/ TOWN ENGINEER AND FIELD SUPERINTENDANT - OPT TO RUN NEW MILL AND INSTALL FLOAT IN BIT SUB. 9/11/2010 00:00 - 01:30 1.50 CLEAN P DECOMP CLEAR/ CLEAN RIG FLOOR. M/U JUNK MILLING BHA AS FOLLOWS: - 6 BLADED JUNK MILL, (3) JUNK SUBS, BIT SUB, BUMPER SUB - OIL JARS, PUMP OUT SUB, & (9) 4 3/4" DCS, OVERALL LENGTH 315.91'. 01:30 - 06:00 4.50 CLEAN P DECOMP RIH W/ MILLING BHA ON 3 V2" DP. BOP DRILL W/ RIH, 1MIN 47 SEC WELL SECURE - 55 STANDS IN, CIRCULATE 2 BPM / 200 PSI, 6 BBLS PUMPED. _ - FLUID LEVEL IS STAYING UP IN DRILL PIPE 06:00 - 06:30 0.50 CLEAN P DECOMP RIG SERVICE AND PERFORM PRE -TOUR CHECKS. 06:30 - 07:00 0.50 CLEAN P DECOMP PJSM - DERRICK INSPECTION. 07:00 - 10:30 3.50 CLEAN P DECOMP CONTINUE TO RIH F/ 55 STANDS TO STAND 96 -KELLY UP 10:30 - 11:00 0.50 CLEAN P DECOMP WASH F/ 10,827' T/ 10,006' MD -SPR 2 BPM / 380 PSI -WASH FILL F/ 10,006'T/ 10,016' MD TOP OF FISH. -PUW 205K, SOW 105K, RT WT 125K. TQ 325 AMPS. -4 BPM/ 1270 PSI 11:00 - 12:30 1.50 CLEAN P DECOMP PUMP 30 BBL FLO -VIS SWEEP SURFACE TO SURFACE -ADD 2 DRUMS SAFE -LUB F/ TQ CONTROL. _ -4 BPM/ 1270 PSI 12:30 18:00 5.50 CLEAN P DECOMP M ILL AND PUSH BRIDGE PLUG - F/ 10,016' T/ 11,201' MD -USE KELLY TO PICK -UP SINGLES FROM PIPE SHED AND -MAKE MOUSE HOLE CONNECTIONS. -PUW 205K, SOW 105K, RT WT 125K. TQ 325 AMPS. WOB 1 OK. -4 BPM/ 1270 PSI -PUMP 20 AND 45 BBL FLO -VIS SWEEPS AS NEEDED. LOTS OF CEMENT RETURNS. 1 18:00 18:30 0.50 CLEAN P DECOMP PERFORM PRE -TOUR CHECKS. 18:30 - 20:00 1.50 CLEAN P DECOMP RESUME MILLING TO PUSH BRIDGE PLUG DOWN - F/11,201' MD j( -TAG HARD g 11,346' UMP 50 BBLS HI VIS SWEEP & CBU. CLEAN UP WELLBORE 20:00 - 20:30 0.50 CLEAN P DECOMP PJSM: DISCUSS FLUID SWAP WITH ALL PARTIES INVOLVED. Printed 11/4/2010 12:24:17PM Noffll America - ALASKA - BP � Page a s of 23 Operation SummaryRepo rt. Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 A ctive Datum: 22 : 33 3/25/1999 16:00 @46.80ft (ab Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 - 23:00 2.50 CLEAN P DECOMP PUMP 50 BBLS 2% KCL. PLUMB IN TRUCKS, FILL PIT 2 W/ 9.6 BRINE, PUT REMAINDER FROM TANK IN VACUUM TRUCK. 23:00 - 00:00 1.00 CLEAN P DECOMP LINE UP AND PUMP 30 BBLS PERF PILL & CHASE W/ 9.6 PPG BRINE, 5 BPM / 1100 PSI. - SHIPPING RETURNS TO TIGER TANK 9/12/2010 00:00 - 01:30 1.50 CLEAN P DECOMP CONTINUE TO CIRCULATE 9.6 PPG BRINE AROUND, 5 BPM / 100 PSI. - DID NOT GET MUCH BACK W/ SWEEP. 01:30 - 05:00 3.50 CLEAN P DECOMP ESTABLISH PARAMETERS: 195K UP WT, 117K DOWN WT, 134K ROTATING WT. - TAG TOP OF CMT SPOTTED ON BRIDGE P LUG @ 11,345'. - 4 BPM, 1250 PSI, 85 RPM, 10K TORQUE. MILL CEMENT TO 11,352', 28' iN ON KELLY. - TOP OF BRIDGE PLUG @ 11,352'. MILL ON BRIDGE PLUG W/ 10 - 12K WOB. - PUSH ON DOWN TO 10,360', LOSS RATE W/ _ PUMPING, 35 BPH. 05:00 - 05:30 0.50 CLEAN P DECOMP PJSM. CLOSE ANNULAR, BULLHEAD 50 BBLS9.6 PPG BRINE - 2.5 BPM / 1700 PSI 05:30 - 08:00 2.50 CLEAN P DECOMP CBU @ 4 BPM / 1270 PSI, ANNULAR CLOSED CIRCULATING THRU CHOKE & GAS BUSTER TO PITS LOSS RATE W/ PUMPING, 8 BPH - OPEN WELL, LOSS RATE 10 -12 BPH - REPORT LOSS RATE TO ADW RWO ENGINEER 08:00 - 09:30 1.50 CLEAN P DECOMP PJSM. SPOT 50 BBL PERF PILL ABOVE PERFS @ 11,374' - BULLHEAD 10 BBLS INTO PERFS @ 2 BPM / 700 PSI - FINAL BULLHEAD PRESSURE, 2 BPM / 1560 PSI. - PUMPS OFF, PRESSURE 800 PSI, 5 MIN - 340 PSI, 10 MIN - 110 PSI, 15 MIN - 10 PSI. 09:30 - 11:00 1.50 CLEAN P DECOMP CONTINUE TO PUSH/ MILL BRIDGE PLUG F/ 11,360' - 11,394' DPM. - 205K UP WT, 11 OK DOWN WT, 137K ROT WT, WOB 12 - 15K - 10,000 - 12,000 FT /LBS TORQUE, 3 BPM / 750 PSI. 11:00 - 12:00 1.00 CLEAN P DECOMP CONTINUE TO CIRCULATE PERF PILL TO SURFACE, (40 BBLS) - DISCUSS PLAN FORWARD WITH ADW RWO ENGINEER. 12:00 - 18:00 6.00 CLEAN P DECOMP SET BACK KELLY, UD (4) JTS. POOH - PIPE PULLING WET AFTER 16 STDS, DROP DART, SHEAR PUMP OUT SUB. - CONTINUOUS HOLE FILL, LOSS RATE 8 - 10 BPH. CONTINUE TO POOH. 18:00 - 18:30 0.50 CLEAN P DECOMP SERVICE RIG, PERFORM PRE TOUR CHECKS. 118:30 - 19:30 1.00 CLEAN P DECOMP CONTINUE TO POOH W/ 3 1/2" DP & JUNK I MILLING BHA. 118 STDS. Printed 11/4/2010 12:24:17PM W orth America:- ALAsKA - BP' Page 1s Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 A Dat um: 22: 33 3/25/19 16:0 @4 6.80ft (ab M ean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 21:30 2.00 CLEAN P DECOMP STAND BACK DRILL COLLARS, BREAK DOWN BHA EMPTY JUNK SUBS, UD MILL. EXTREME WEAR IN CENTER OF MILL - WEAR IN CENTER IS 1 'V2" ACROSS AND 1 1/2" DEEP, TAPERING INWARD. - M/U JUNK SUBS & BHA, BLIND RAMS CLOSED, CONSTANT HOLE FILL. - STATIC FLUID LOSS RATE, 5 BPH. 21:30 22:30 1.00 CLEAN P DECOMP CONDUCT WEEKLY SAFETY MEETING. - MEETING REVOLVES AROUND SAFETY VIDEO, REMEMBER CHARLIE - DISCUSSION HIGHLIGHTS NOT SHORT CUTTING AND WATCHING OUT FOR EACH ' OTHER. 22:30 23:30 1.00 CLEAN P DECOMP FINISH MAKING UP BHA AS FOLLOWS: -6 BLADED JUNK MILL. (3) JUNK SUBS, BIT SUB W/ FLOAT - BUMPER SUB, OIL JARS, PUMP OUT SUB, (9) 4 3/4" DCS. OAL 317.33'. 23:30 - 00:00 0.50 CLEAN P DECOMP PJSM. RIH ON 3 1/2" DP. 9/13/2010 00:00 - 04:30 4.50 CLEAN P DECOMP CONTINUE TO RIH W/ MILLING BHA ON 3 1/2" DP 04:30 - 06:00 1.50 CLEAN P DECOMP TAG UP ON BRIDGE PLUG 8' IN ON KELLY @ 11,394' - MILL ON BRIDGE PLUG, 4 BPM (cil 120OPS1, 195K UP WT, 112K DOWN WT, - 134K ROT WT. 80 RPM, 10 -15K WOB, 11- 12,000 FT /LBS ON BTM TORQUE - BROKE ON THROUGH, PUSHING BRIDGE PLUG DOWN HOLE, KELLY DOWN. 11,420'. MAKE CONNECTION & WASH ON DOWN TO 11,452'. 06:00 - 06:30 0.50 CLEAN P DECOMP PJSM. MAKE CONNECTION AND CONTINUE TO MILL AND PUSH BRIDGE I?l UG - C LEANED OUT T/ 11,475' MD 5 BPH LOSS RATE. 06:30 - 08:30 2.00 CLEAN P DECOMP CIRCULATE 50 BBL FLO -VIS SWEEP SURFACE TO SURFACE -5 BPM/ 1340 PSI -TILL RETURNS ARE CLEAN OF SAND. 1 BBLS SAND) -SET BACK KELLY AND LD (2) JTS. 08:30 - 09:30 1.00 CLEAN P DECOMP SPOT 48 BBLS PERF PILL ABOVE THE PERF AT 11,374' - 11,394' MD. -PICK UP 12 FT ABOVE THE TOP PERF AT 11,374' MD -BULL HEAD 5 BBLS OF PERF PILL INTO FORMATION AT 2 BPM / 1220 PSI -PUMPS OFF SHUT IN PRESSURE IS 900 PSI, 5 MIN = 230 PSI, 10 MIN = 30 PSI, 0 PSI IN 13 MIN. 1 09:30 - 10:30 1.00 CLEAN P DECOMP PJSM. POH F/ 11,362' MD FOR PERF RUN. -LD 15 JTS 3 1/2" DP 1X1 TO PIPE SHED _ - CONTINUOUS HOLE FILL 10:30 - 12:00 1.50 CLEAN N RREP 1 10,890.00 DECOMP REPAIR EJECTOR RAM CYLINDER ON PIPE HANDLER. Printed 11/4/2010 12:24:17PM Nortii America - ALASKA -BP Page20 of 23 Operation Summary 'Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active Datum: 22 3 16:00 @46. (ab ove Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 18:00 6.00 CLEAN P DECOMP CONTINUE TO POH F/10,890' MD -LD 3 V2" DP 1X1 TO PIPE SHED. - CONTINUOUS HOLE FILL.-3 BPH LOSS RATE - UNANNOUNCED PIT GAIN WITH RELIEF DRILLER, -BOP DRILL WHILE UD DRILL PIPE. AAR: FAIL TO ANNOUNCE DRILL ON HARMONY RADIO. -LEFT 24 HRS NOTICE OF UP COMING BOPE TEST ON 659 -3607 PAGER AT -12:05 HRS 9/13/2010. -CHUCK SCHEVE AOGCC STATE INSPECTOR RETURNED CALL AT 12:15 HRS 9/13/2010 -AND SAID CALL WITH A (2) HRS NOTICE PRIOR TO BOPE TEST. 18:00 - 18:30 0.50 CLEAN P DECOMP PERFORM PRE TOUR CHECKS AND SERVICE RIG 18:30 - 20:00 1.50 CLEAN P DECOMP PJSM. SLIP & CUT 84' OF DRILLING LINE. 20:00 - 00:00 4.00 CLEAN P DECOMP CONTINUE TO POOH & UD 3 V2" DP. CONTINUOUS HOLE FILL. 9/14/2010 00:00 - 01:00 1.00 CLEAN P DECOMP CONTINUE TO LAY DOWN MILLING BHA, CLEAN OUT JUNK SUBS, LOAD OUT MILLING EQUIPMENT. 01:00 02:00 1.00 CLEAN P DECOMP CLEAR / CLEAN RIG FLOOR, RIG DOWN PIPE _ SPINNERS. 02:00 - 03:00 1.00 CLEAN P DECOMP PJSM. N/U DUTCH RISER 03:00 06:00 3.00 PERFRE P DECOMP SAFETY MEETING WITH ALL HANDS AND SCHLUMBERGER - DISCUSS WEIGHTS OF EQUIPMENT TO BE BROUGHT TO FLOOR - IDENTIFY HAZARDS AND HOW TO MITIGATE SAME. - AGREE TO STOP, TALK AND ADJUST WHEN NECESSARY - RIG UP E LINE EQUIPMENT 06:00 13:30 7.50 PERFRE P DECOMP PJSM WITH DAY CREWS. RU E -LINE EQUIPMENT - LUBRICATOR TESTED TO 500 PSI FOR 5 CHARTED MIN. - MU AND RUN R1CCL WITH 20' OF_I D 5 S_ff_ 1 2DEG_ PHASIN P JET OMEGA. -RIH - TALKED TO AOGCC STATE INSPECTOR CHUCK SCHEVE, AGREED TO GIVE 2 HRS NOTICE PRIOR TO START OF BOPE TEST. 0935 HRS 9/14/2010. 13:30 16:00 2.50 PERFRE P DECOMP PERF GUN ON DEPTH. P ERFORATE F/ 11.374 - 11 MONITOR WELL, NO SIGNIFICANT INCREASE IN FLUID LOSS, NO FLOW -POOH SAFETY MEETING. L/D PERF ASSEMBLY, ASF. 16:00 - 18:00 2.00 PERFRE P DECOMP PJSM. RIG DOWN E LINE. 18:00 - 18:30 0.50 PERFRE P DECOMP PERFORM PRE TOUR CHECKS, SERVICE RIG. Printed 11/4/2010 12:24:17PM o America - ALASKA - BP Rage 21 of=23 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWL 500292272900 Active Datum: 22: 33 3/25/1999 16:00 @46.80ft (abo Mean Se L Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 20:00 1.50 PERFRE P DECOMP FINISH RIGGING DOWN E LINE, N/D DUTCH RISER. - PULL WEAR BUSHING, SET TEST PLUG 20:00 - 00:00 4.00 BOPSUR P DECOMP CONDUCT FULL TEST ON _135/8" X 5M BOPE D TEST ALL COMPONENTS @ 250 / 4500 PSI �ar TEST ANNULAR @ 250 / 3500 PSI WITNESSING OF TEST WAIVED BY CHUCK SCHEVE, AOGCC. 9/15/2010 00:00 - 01:30 1.50 BOPSUR P DECOMP CONTINUE TESTING 13 5/8" X 5M BOPE AS PER AOGCC REQUIREMENTS ALL TESTS @ 250 / 4500 PSI, ANNULAR TESTED TO 250 / 3500 PSI - CONDUCT DRAWDOWN TEST ON ACCUMULATOR &CHECK N2 BOTTLES 01:30 - 02:00 0.50 BOPSUR P DECOMP RIG DOWN TEST EQUIPMENT. PULL TEST PLUG. 02:00 03:00 1.00 RUNCOM P RUNCMP RIG UP TO RU 2 7/8" EUE 8RND TUBING. - RIG UP FLOOR EQUIPMENT, TUBING TONGS 03:00 - 06:00 3.00 RUNCOM P RUNCMP PJSM RIH W /'2 7/8" EUE 8 RND TUBING FROM PIPE SHED 06:00 06:30 0.50 RUNCOM P RUNCMP SERVICE RIG. - CHECK AND SET PUTS INSPECT DERRICK SERVICE DRAW WORKS 06:30 08:00 1.50 RUNCOM P RUNCMP TIH WITH 2 7/8" TUBING AND STAND BACK IN DERRICK. 08:00 09:00 1.00 RUNCOM P RUNCMP CLEAN AND CLEAR RIG FLOOR. 109:00 - 10:30 1.50 RUNCOM P RUNCMP RU TO RUN ESP COMPLETION ON 2 7/8" TUBING FROM DERRICK. - PJSM AND HANG SECOND SHEAVE IN DERRICK. - PULL ESP CABLE AND CAPILLARY TUBE THROUGH SHEAVE TO RIG FLOOR. 10:30 - 15:00 4.50 RUNCOM P RUNCMP PU AND SERVICE ESP MOTOR AND PUMP ASSEMBLY. MU CAPILLARY TUBE TO CENTRALIZER. MU MLE AND CONNECT TO ESP MOTOR ASSEMBLY. - TEST CAPILLARY TUBE CHECK VALVE TO 3500 PSI - GOOD TEST. - PERFORM INITIAL ESP CABLE TEST - GOOD TEST. 1500 - 1800 3.00 RUNCOM P RUNCMP RIH W/ ESP COMPLETION ON 2 7/8" TUBING FROM DERRICK. - OPTIMUM TORQUE FOR 2 7/8" EUE 2300 FT -LBS. - CANNON CLAMPS ON EVERY JT, FOR CAPILLARY TUBE AND ESP CABLE. - TEST CAPILLARY TUBE EVERY 1000' - TEST ESP CABLE EVERY 2000' - FILL TUBING WHILE TESTING, BREAK CIRCULATION AND PUMP 10 BBLS DOWN TUBING. - 1 BPM / 1900 PSI W/ PUMPING. 18:00 - 18:30 0.50 RUNCOM P RUNCMP CONDUCT PRE TOUR CHECKS, SERVICE RIG. Printed 11/4/2010 12:24:17PM orth America -ALASKA -BP Page 22 of23 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 1/9/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active Datum: 22 : 33 3/25/1999 16:00 @46.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 00:00 5.50 RUNCOM P RUNCMP RIH W/ ESP COMPLETION ON 2 7/8" TUBING FROM DERRICK. - CANNON CLAMPS ON EVERY JT. FOR CAPILLARY TUBE AND ESP CABLE. TEST CAPILLARY TUBE EVERY 1000' TEST ESP CABLE EVERY 2000' FILL TUBING WHILE TESTING, BREAK CIRCULATION AND PUMP 10 BBLS DOWN TUBING. - 1 BPM / 1900 PSI W/ PUMPING. 9/16/2010 00:00 - 04:00 4.00 RUNCOM P RUNCMP 79 STANDS IN. MAKE REEL TO REEL SPLICE IN ESP CABLE. - PUMP DOWN TBG,10 BBLS, 1 BPM / 1950 PSI. - CONDUCT CONDUCTIVITY TEST ON ESP CABLE, OK. BRING HEAT TRACE CABLE OVER SHEAVE. 04:00 - 04:30 0.50 RUNCOM P RUNCMP CONTINUE TO RIH W/ 2 7/8" ESP COMPLETION STRING. 81 STANDS 04:30 - 06:30 2.00 RUNCOM P RUNCMP MAKE REEL TO REEL SPLICE ON 3/8" CAPILLARY TUBE. 06:30 - 09:00 2.50 RUNCOM P RUNCMP CONTINUE TO RIH W/ 2 7/8" ESP COMPLETION STRING - 255 JTS RUN. MAKE UP HEAT TRACE. 09:00 - 13:00 4.00 RUNCOM P RUNCMP CONTINUE TO RIH W/ 2 7/8" ESP COMPLETION STRING. - RUNNING ESP CABLE, 3/8" CHEM INJ LINE AND HEAT TRACE - RUNNING CANNON CLAMPS CONTINUOUS FOR LINES 13:00 14:00 1.00 RUNCOM N SFAL RUNCMP CAPILLARY LINE CRIMPED, SPLICE SAME - CENTRILIFT CRIMPER FAILED, EXPEDITE REPLACEMENT CRIMPER 14:00 00:00 10.00 RUNCOM P RUNCMP CONTINUE IN HOLE W/ 2 7/8" ESP COMPLETION STRING. - HOLE STAYING FULL, GIVING BACK A LITTLE LESS THAN DISPLACEMENT - RUNNING CANNON CLAMPS CONTINUOUS FOR (3) LINES. 9/17/2010 00:00 - 01:30 1.50 RUNCOM P RUNCMP CONTINUE TO RIH W/ 2 7/8" ESP COMPLETION STRING - RUNNING CONTINUOUS CANNON CLAMPS ON (3) LINES. - CHANGED OUT (3) BAD JTS .... (SLIP DAMAGE) - 355 JTS TOTAL RUN 01:30 - 06:00 4.50 RUNCOM P RUNCMP PICK UP AND MAKE UP TUBING HANG R - INSTALL PENETRATORS j - DISCOVER HANGER MACHINED TO ACCEPT 1/4" FITTING FOR CHEMICAL INJECTION, (CAPILLARY) LINE. CALL TOWN ENGINEER AND GET PERMISSION TO ATTACH 1/4" CONTROL LINE TO HANGER AND SWEDGE UP TO 3/8" CAPILLARY LINE. PARTS COMING FROM PRUDHOE SIDE. - CONTINUE TO MAKE FIELD CONNECTIONS ON HEAT TRACE AND ESP CABLE. - TEST CONNECTIONS ON HEAT TRACE AND ESP CABLE, OK MAKE SPLICE ON CAPILLARY TUBE, SWEDGE DOWN TO 1/4 ". Printed 11/4/2010 12:24:17PM r AWorth America - ALASKA - BP Page 23 of 23 Operation Summary Report Common Well Name: MPK -33 AFE No Event Type: WORKOVER (WO) Start Date: 8/30/2010 End Date: X4- OORF8 -E (1,125,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 119/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292272900 Active Datum: 2 2: 33 3/25/1999 16:00 @4 6.80ft (a bove Mean Sea Lev el) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 07:00 1.00 RUNCOM P RUNCMP PJSM. ORIENT AND LAND HANGER, RILDS. TWC INSTALLED. 07:00 - 08:30 1.50 RUNCOM P RUNCMP PJSM. TE TWC VALVE TO 4500 PSI 10 MIN / CHARTED, OK. j TEST FROM BOTTOM @ 500 PSI, PUMPING AWAY 6 BPM, 10 MIN / CHARTED. 08:30 09:00 0.50 RUNCOM P RUNCMP PJSM. RIG DOWN SHEAVES, RAISE BEAVER SLIDE. 09:00 - 10:00 1.00 BOPSUR P RUNCMP PJSM. REMOVE RAMS F/ SINGLE GATE. 10:00 - 18:00 8.00 BOPSUR P RUNCMP CONTINUE TO N/D STACK, REMOVE SINGLE GATE OPERATOR - N/U ANNULAR PREVENTOR ON 3 RAM STACK UP. 18:00 - 00:00 6.00 BOPSUR P RUNCMP CONTINUE TO CONFIGURE BOPE TO 3 RAM STACK UP - JACK RIG DOWN TO REFASTEN DRIP PAN & REFASTEN SAME. 9/18/2010 1 00:00 - 01:00 1.00 BOPSUR P RUNCMP N/D STACK AND STAND BACK ON PEDESTAL. 01:00 - 03:30 2.50 WHSUR P RUNCMP PJSM N/U ADAPTER FLANGE. 03:30 - 04:00 0.50 WHSUR P RUNCMP PERFORM FINAL TESTS ON ESP CABLE AND HEAT TRACE TEST CAPILLARY LINE, OK. 04:00 - 05:00 1.00 WHSUR P RUNCMP PJSM. N/U TREE. - TEST TREE TO 5000PSI WITH DIESEL - GOOD TEST. 05:00 - 06:00 1.00 WHSUR P RUNCMP RU LUBRICATOR AND TEST TO 4500 PSI. PULL TWC AND INSTALL BPV. TEST BPV FROM BELOW TO 500 PIS FOR 5 CHARTED MINUTES. SECURE WELL RIG RELEASED @ 0600 HRS, 09/18/2010 Printed 11/4/2010 12:24:17PM BOPE use • • Page 1 of 1 Regg, James B (DOA) From: Miller, Kenneth C [kenneth.miller2@bp.com] Sent: Saturday, September 04, 2010 10:31 PM ~~~ ~~~ 1~0 To: DOA AOGCC Prudhoe Bay Cc: AKDCRig4ESWeIISiteLeader@bp.com; Reem, David C; steven.rossberg@bp.com; CismosDA@BP.com; Harry.Engel@bp.com; kilfoyja@bp.com; Samantha.Shepard@bp.com; SmartJC@BP.com; NademM@BP.com Subject: BOPE use !u1.~t i~-~3 Attachments: MPK-33 BOPE use.doc ~'~ iab-- ~z- Here is the BOPE use form for MPK-33 Annular used to contrQ_tra~~ec~ "Packer has" or fluid bleeding back from Bull Head operation. «MPK-33 BOPE use.doc» ~ R, -, Ken Miller CTD & RWO Operations Supt Slope Ofc: 907-659-5329 Cell: 907-227-9214 Harmony: 2157 9/7/2010 C~ Blow Out Preventer Equipment (BOPE Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any_ BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: Ken Miller Wellsite Leader Name: Dave Rhodes Contact Number: 659-5329 Contact Number: 659-4608 Traction Number: 2010-IR-3609045 Well Location & Name and Ri Name: MPK-33 - Nabors 4ES - Permit To Drill PTD Number: 1962020 Date and Time of Incident: 9/4/2010 - 12:30 Hours Original Scope of Work: Mill up 7" Bridge plug @ 9330' MD, Bull Head 50 bbl Gel pill, push plug to 11,341' MD. Operational Description Leading up to Well Control Event: Mill up 7" Bridge plug @ 9330' MD, Bull Head 50 bbl Gel pill, push plug to 10,638' MD. Mill on Bridge plug stuck at 10,638' md. Stop Milling operation and circulate abottoms-up (with a 6-10 bph loss rate). Prior to bottoms-up, a small amount of gas was observed at the Rig floor Bell-ni ple. The Well was shut-in with the Annular, an icipa ing possible trapped pressure. No shut-in pressure noted, No pit gain. Finished circu a mg through the Choke Gas Buster to the Pits. BOPE Used and Reason: Annular used to control tra ed "Packer Gas" or fluid bleedin back from Bull Head o eration. Is a BOPE Test Required after use (Yes / No): If no, why? Yes 24 hour notice required to NS AOGCC Ins ectors prior to testin BOPS com onents. Plan Forward: Finish TOH and re-test annular with 2 7/8" test joint Additional Comments: Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa.aoacc.prudhoe.bav(a~alaska.aov Email CC List BP WSL Har En el Wells Team Leader Jeff Kilfo le En ineerin Team Leader O erations Drillin En ineer- Well File Wells O erations Mana er Drillin & Com letions En ineer Mana er Wells Intervention Mana er BOPE Usage Report for AOGCC August 2, 2010 HRE • • ~~Q~~ 0~ a~Q~~{Q /,~.~..ELL~o~~ David Reem Engineering Team Leader BP Exploration (Alaska), Inc. ~~ W~~~~~'~~' v~u~. :~, ?~~1s i1 P.O. Box 196612 r r, a.d O" Anchorage, AK 99519-6612 ~ lp Re: Milne Point Field, Kuparuk River Oil Pool, MPK-33 Sundry Number: 310-212 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set aut in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this 'r/~day of July, 2010. Encl. r~ STATE OF ALASKA "' ~~~' ALASK~L AND GAS CONSERVATION COMMIS~I ~` APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: ^ Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ®Plug Perforations ~ ^ Perforate ®Pull Tubing . ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ®Other Re-Open Sag River Perfs 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development• ^ Exploratory 196-202 3. Address: ^ Service ^ Stratigraphic 6. API Number: ' P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22729-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPK-33 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): t~~e !~~ c„~,, ADL 375132 Milne Point Unit / Kuparuk River ~Sahd , f~f. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11543' 9310' 11483 9251' 9320' & 11341' None Casin Len th Size MD TVD Burst Colla e Structural Conductor 7 ' 2 112' 11 ' Surface 66 0' 9-5/8" 6' 4948' 5750 30 0 Intermediate Production 11492' 7" 1 2 724 54 Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9280' - 9316' 7070' - 7106' 2-7/8", 6.5# L-80 9137' Packers and SSSV Type: None Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 15, 2010 ®Oil ! ^ WINJ ^ WDSPL ^ Plugged 16. Verbal Approval: Date: ^ Gas ^ GINJ ^ GSTOR ^ Abandoned ^ WAG ^ SPLUG ^ Suspended Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Na David R m Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date ~-j~ - zo/p Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval: N ity Commission so that a representative may witness ~© .. l /~ t Sundry Number: ,,_, _ al Integrity Test ^ Location Clearance ^ Plug Integrity LiQ BOP Test ^ Mechanic / Other: * Z ~-~ QS ~ ~n.-..~-~-t eS'1<'- ~ n`•"') It `,~V~~ Y ~V r JUL 1 ~ ~ii1~l Subsequent Form Required: ~ a -- `f (~`( Alaska Dil & 6aii Cars. (,'OtrMYtIS510t! kncherage APPROVED BY ~~~J_D ~~~ //~~ Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 Re~f~(~Oi@ ~UL 2 0 tom ORIGINAL ~-z~ ~~ ~r ~~ Submit In Duplicate , I:oc~~i~ ~~~yl~ • • MPK-33 Rig Workover (squeeze Kuparuk perfs and re-open Sag perfs) Scope of Work: Pull 2-7/8" L-80 ESP completion. Drill up 7" CIBP C~3 9320'. Set and test composite bridge plug below Kuparuk perfs. Cement off Kuparuk perfs with a cement retainer: Drill up retainer, composite bridge plug, and CIBP @ 11,341. Run 2-7/8" L-80 ESP completion. ~° ?~?,. Engineer: Hank Baca s~~ B f{P ~ X13 SU p s:- ~? 8TS" ~ vl> MASP: 2189 psi Well Type: Producer Estimated Start Date: August 15th, 2010 Proposed Procedure 1. MIRU. ND tree. NU and test BOPE (consisting of annular, 2-7/8" x 5" VBRs, blind/shear) to 250 psi low/35,QQ~si high. Circulate out freeze protection with seawater. '- 2. LD ESP completion. 3. PU 6.125" bit & scraper on drill pipe and drill up 7" CIBP @ 9320'. 4. PU 7" composite bridge plug/RTTS. Set composite bridge plug @ 9380, PUH and set RTTS to test bridge plug to 2000 psi and casing to 2000 psi. 7w• G~~ RTTS ~- "- `~ 3~ o ~ o 5. PU cement retainer and set C«~ 9200'. s.~S .~. g2ov ` N~ 6. Squeeze off Kuparuk perfs. Sting out of retainer leaving ~5 sx on top of retainer. 7. Drill up retainer and squeeze cement. Test squeeze to 500psi. 8. Continue in hole and drill up CIBP C«3 11,341'. POOH LD drill pipe'/ ' 9. Run 2-7/8" L-80 ESP completion to 11,300' - 10. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. Q~ ro ~~~s 1~G9 li /psivK Q! ~f ~/9S p~ro~~ ~ ~~4a~ Q from ~ w~ ~~u~ IOD~ , b/el1 ~,a~ ~ ~ / ~~~.'dl~` - ~ (~ G Cw 'l. ~T I ~'1 ) lQG~4'r~C ~r/Q! I ~T ~C ~U~ ®'~ ~'/ A~ no ~Pn,,~~~`y le /'eo Phr~y Th~~~ aye ;~P k a~vk Qerfs a4~ 1~ el~ qh~ S~~ZZ~~ ~ ,~ j~,,5 w , ®~vC~"~~ iS l~{ vOfP~~ r ~ ~ ~~~ ~'~P~ ~-~~ ~'~~ ~' ~~y~~ ~~ ~ EE: 2-9/16" - 5M .Cooper LLHEAD:11"x 7-1/16" SM FMC Ger~ 7"x 2-7/8" FMC Hanger w/ 3" LH Acm p, 2.5" CIW H BPV profile MPK-33 Orig. KB v. = 61.8 (N27E) Orig. GL~. = 27.8 (N27E) Ong. KB to F = 19.8 (N4ES) Conductor Casing 112' 9 5/8" 40 ppf L-80 casing 6666' KOP @ 380' Max Hole Angle: 58° @ 3840' MD Angle thru perts = 7° Max DLS = 4.34° @ 7311' MD 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btrc. prod. casing ( drift ID = 6.151", cap. = 0.0383 bpf ) ( cap. of IA w/ tbg inside = 0.02758 bpf) Stimulation Summary Perforation Summary Ref loa: GR/CCL 01/29/97 Size SPF Interval (TVD) 4.5" 5 9280 - 9306 7088'-7095' 3 3/8" * 4 9306 - 9316 7095'-7105' 3 3/8" ` 4 9328 - 9334 7117'-7123' 'shot 6/27/01 w/ Schlumberger Powerjet guns 15 bbls, 75 sx "G" 15.8# cement Camco 2-7/8" x 1 ° 88' I sidepocket KBMM GLM Camco 2-7/8" x 1" 8924` I sidepocket KBMM GLM 2-7/8" XN nipple 9066` (ID 2.205") Pump, 160 P11 Coated STG. ` Model - SXD 9080 Gas Separator gOgg~ GAS MASTER Coated Intake 9,098' MD = 6890' TVD Tandem Seal Section 9103' GSB3 DB UT/LT SB/SB PFSA/FSA Motor, 152 HP, 2325 volt, 9117` 40 amp, Model KMH PumpMate XTO w/6 fin 9131 ` centralizer and anode Intake 9,131` MD = 6922' TVD 7^ Bridge Plug 9320' Abandoned Sag River Perforations: 11341' 7" HES Bridge Plug Size SPF Interval (TVD) 4.5" 5 11374'-11394' 9143'-9162' 7" float collar (PBTD) 7" 26 ppf L-80 BTRS 11483' 11525' DATE REV. BY COMMENTS 02/13/97 02/24/x8 MDO M. under ESP Completion a-ES MILNE POINT UNIT WELL K 33 04/02/99 JWS Conversion from Sad River to Kuparuk 4ES - API NO: 5~-~29-22729 06/29/01 B. Hasebe RWO Nabors 4ES 05/01/04 Lee Hulme RWO Nabors 4-ES BP EXPLORATION (AK) 08/09/08 Lee Hulme RWO Nabors 3S u.r7t ~~ is EE: 2-9/16" - 5M Cooper LLHEAD:11"x 7-1/16" 5M FMC Gen 7"x 2-7/8" FMC Hanger w/ 3" LH Acme p, 2.5' CIW H BPV profile Conductor Casing 1 12' 9 5/8" 40 ppf L-80 casing 6666' KOP @ 380' Max Hole Angle: 58° @ 3840' MD Angle thru perfs = 7° Max DLS = 4.34° @ 7311' MD 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btrc. prod. casing ( drift ID = 6.151", cap. = 0.0383 bpf ) ( cap. of IA w/ tbg inside = 0.02758 bpf) Stimulation Summary Perforation Summary Ref loa: GR/CCL 01129/97 Size SPF Interval (TVD) 4.5" 5 9280 - 9306 7088'-7095' 3 3/8" ' 4 9306 - 9316 7095'-7105' 3 3/8"' 4 9328 - 9334 711 T-7123' 'Kuparuk perfs squeezed off Re-opened Saa River Perforations: Size SPF Interval (TVD) 4.5" 5 11374'-11394' 9143'-9162' DATE REV. BY COMMENTS 02/13/97 02/24/98 MDO M. Linder ESP Completion 4-ES 04/02/99 JWS Conversion from Sad River to Kuparuk 4ES 06/29/01 B. Hasebe RWO Nabors 4ES 05/01/04 Lee Hulme RWO Nabors 4-ES 08/09/08 Lee Hulme RWO Nabors 3S Orig. KB Elev. = 61.8 (N27E) Orig. GL~. = 27.8 (N27E) Orig. KB F = 19.8 (N4ES) Camco 2-7/8" x 1" _gg' I sidepocket KBMM GLM 2-7/8" ESP 7" float collar (PBTD) 11483' 7" 26 ppf L-80 BTRS 11525' MILNE POINT UNIT WELL K-33 API NO: 50-029-22729 BP EXPLORATION (AK) ~ 1vIPK-33 Workover (PTD 196-202) Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, July 20, 2010 9:09 AM To: 'Reem, David C' Cc: Baca, Hank Subject: RE: MPK-33 Workover (PTD 196-202) Dave, Thanks... makes perfect sense. Page 1 of 1 Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) _ _ _ _ _ From: Reem, David C [mailto:ReemDC@BP.com] Sent: Monday, July 19, 2010 2:20 PM To: Schwartz, Guy L (DOA) Cc: Baca, Hank Subject: MPK-33 Workover (PTD 196-202) Guy, Hank is out catching fish in Cordova, Bjork is hooked up doing other stuff, so I'll take a run at answering your questions on MPK-33. Your first questions were: 1. Is the MASP based on the TVD of the Sag or the Kuparuk sands??? What are you using for completion fluid?? Expected individual reservoir pressures ?? 2. When you run the RTTS to test the Composite plug and casing you would have to set it twice .. once below the Kuparuk perfs and once above. Is this assumption correct. Not clear in your procedure. The MASP is based on the TVD of the Kuparuk. This will change when we open up the Sag River. We will be prepared to face 4350 psi reservoir pressure (8750' tvd) prior to milling up the cast iron bridge-plug at 11341'md (which answers your later question....this plug will be gone when we are done with this Workover). We will be weighted up to a 9.8 ppg brine prior to drilling up this plug and opening up the Sag River. Prior to drilling up this plug and opening the Sag, the fluid will be seawater unless a static bottomhole pressure survey that will be run a few days prior to us rigging up on the well indicates a higher reservoir pressure. You are correct, we will set the RTTS twice, once below the Kuparuk perfs to test the composite plug, and once above the Kuparuk to test the casing to surface. Let me know if there are add't questions or if I need to add more detail. Thanks DCR 7/20/2010 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ACID TREATMENT .• Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension ~ W y Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' . Exploratory ~~ 196-2020 ' 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22729-00-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 61.1 DF MPK-33 8. Property Designation: 10. Field/Pool(s): . ADLO-375132 MILNE POINT Field/ KUPARUK RIVER OIL Pool 11. Present Well Condition Summary: Total Depth measured 11543 feet Plugs (measured) 9320' BP 11341' BP true vertical 9310.09. feet Junk (measured) None Effective Depth measured 11483 feet true vertical 9251 feet Casing Length Size MD TVD Burst Collapse Conductor 74 20" Surface - 112' Surface - 112' Surface 6630 9-5/8" 40# L-80 Surface - 6666' Surface - 4948' 5750 3090 Production 11492 7" 26# L-80 Surface - 11526' Surface - 9293' 7240 '"5410 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ - True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 SURFACE - 9137 0 0 - Packers and SSSV (type and measured depth) NONE 0 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~~ J~~ ~ ~: j n ~. ~ ~oeJ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 15 2 100 211 Subsequent to operation: 0 ~ 0 0 197 14. Attachments: 15. Well Class after aroposed work: Copies of Logs and Surveys Run Exploratory r Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG GINJ ~ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer (~ ' Signature ! Phone 564-4944 Date 12/12/2008 Form 10-404 R vised 04/2006 `~ ~~ ~1 i ~-E ~" ~ut~~ Submit Original Only ~,~'Z~l~~~~D I1•/rbo MPK-33 196-202 PERF OTTOCHMENT LJ Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPK-33 1/29/97 PER 11,374. 11,394. 9,142.49 9,162.32 MPK-33 3/30/99 BPS 11,374. 11,394. 9,142.49 9,162.32 MPK-33 3/30/99 PER 9,280. 9,306. 7,069.96 7,095.69 MPK-33 6/27/01 PER 9,306. 9,316. 7,095.69 7,105.58 MPK-33 6/27/01 PER 9,328. 9,334. 7,117.45 7,123.39 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE C~ MPK-33 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUM MARY 11/30/2008~T/I/0=200/200/0. (ESP acid treatment) Spear into tbg w/ 10 bbls crude for ~ infectivity. Pump 15 bbls 7.5% DAD acid followed by 3 bbls 60/40 meth & 47 bbls crude down tbg. Caught fluid w/ 6 bbls crude away during flush. Tbg pressure started falling at 27 bbls crude away. Lost total of 300 psi. At 36 bbls away, tbg pressure started to increase. Tbg pressure increased to 2150 psi @ .7 bpm. FWHP=100/160/0. 12/1/2008=(Flush TBG Post Acid treatment) T/I/0= 0/100/0. Pump 90 bbls dead crude; followed by 10 bbls diesel down TBG for Post Acid treatment flush. FWHP= 0/100/0. I FLUIDS PUMPED BBLS 15 7.5% DAD AC I D 3 60/40 METH 147 CRUDE 10 DIESEL 175 TOTAL • STATE OF ALASKA ~ ~ ~~~ ALA OIL AND GAS CONSERVATION COM~SION AU G 2 "~ 200 REPORT OF SUNDRY WELL OPERATIONS Alaska Oi! ~ Gas Cons. Comr~nissian 1. Operations Performed: iv f ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 196-202' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22729-00-00' 7. KB Elevation (ft): KBE = 61.10' 9. Well Name and Number: MPK-33- 8. Property Designation: 10. Field /Pool(s): ADL 375132 ~ Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 11543 feet ~~ ~ ~~ ~''^ _ ~(~v true vertical 9310 ~ feet Plugs (measured) 9320', 11341' Effective depth: measured 11483 feet Junk (measured) N/A true vertical 9251 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 112' 112' Surface 6630' 9-5/8" 6666' 4948' 5750 3090 Intermediate Production 11492' 7" 11526' 9293' 7240 5410 Liner ~~•~Jti~~~ nv a E~ ~tlo~ S.:~CJ' M.,r ~ ~Y Perforation Depth MD (ft): 9280' - 9334'' Perforation Depth TVD (ft): 7070' - 7123' - 2-7/8", 6.5# L-80 9137' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 Subsequent to operation: gg 71 1153 320 220 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O: Exempt: Contact Howard West, 564-5471 N/A Printed Name Sondra Stewman Title Technical Assistant ~/ Prepared By Name/Number. Sig "lure ~ Phone 564-4750 Dat~'~7-(~b Sondra Stewman 564-4750 Form 10-404 Revised 04/2006 ~^"°^a ~ ~ ~ ~ !\ ~ ~ ~ r ; Submit Original C TREE: 2-9116" - 5M Cooper WELLHEAD:11"x 7-1/16" 5M FMC Gen 5A w/ 7"x 2-7/8" FMC Hanger w/ 3" LH Acme Top, 2.5" CIW H BPV profile M P K-33 Orig. KB Elev. = 61.8 (N27E) Orig. GL Elev. = 27.8 (N27E) Orig. KB to BF = 19.8 (N4ES) Conductor Casing 1 12' 9 5/8" 40 ppf L-80 casing 6666' KOP @ 380' Max Hole Angle: 58° @ 3540' MD Angle thru perfs = 7° Max DLS = 4.34° @ 7311' MD 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btrc. prod, casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ) ( cap. of IA w/ tbg inside = 0.02758 bpf) Stimulation Summary Perforation Summary Ref loa: GRICCL 01/29/97 Size SPF Interval (TVD) 4.5" 5 9280 - 9306 7088'-7095' 3 3/8" ' 4 9306 - 9316 7095'-7105' 3 3/6" ' 4 9328 - 9334 7117'-7123' "shot 6/27/01 w! Schlumberger Powerjet guns 15 bbls, 75 sx "G" 15.8# cement Abandoned Sag River Perforations: Size SPF Interval ,TVD) 4.5" 5 11374'-11394' 9143'-9162' Camco 2-7/8" x 1" 88 I sidepocket KBMM GLM Camco 2-7/8" x 1" $g24' sidepocket KBMM GLM 2-7/8" XN nipple 9066' (ID 2.205") Pump, 160 P11 Coated STG . ` Model - SXD 9080 Gas Separator 9098' GAS MASTER Coated Intake 9,098' MD = 6890' TVD Tandem Seal Section 9103` GSB3 D8 UT/LT SB/SB PFSA/FSA Motor, 152 HP, 2325 volt, 8117` 40 amp, Model KMH PumpMate XTO w/6 fin 9131 ` centralizer and anode Intake 9,131' MD = 6922' TVD 7" Bridge Plug 9320' I 7" HES Bridge Plug 11341' 7" float collar (PBTD) 11483' I 7" 26 ppf L-80 BTRS 11525' DATE EV. BY COMMENTS 02/13/x7 ovza/s6 Moo M. Linder ESP Completion 4-ES MILNE POINT UNIT WELL K 33 04/02/99 JWS Conversion from Sad River to Kuparuk 4ES - API NO: 50-029-22729 06/29/01 B. Hasebe RWO Nabors 4ES 05/01(04 Lee Hulme RWO Nabors 4-ES AK} BP EXPLORATION 08/09/08 Lee Hulme RWO Nabors 3S ( • • BP EXPLORATION Page 1 of 3 Qperations Summary Report Legal Well Name: MPK-33 Common Well Name: MPK-33 Spud Date: 1/9/1997 Event Name: WORKOVER Start: 8/4/2008 End: 8/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/9/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/5/2008 06:00 - 09:00 3.00 RIGD P PRE Scope and lower the Derrick. Prepare the Pipe Shed and Pits Modules. Rig down off of MPK-30 and prepare for trucks. Trucks arrive on location at 0800 hrs. Back the Carrier off well slot MPK-30 with the Pad Operator, Well Site Leader and Toolpusher present. 09:00 - 09:30 0.50 RIGD P PRE Mobilize the Carrier to the front well row in front of well slot MPK-33. 09:30 - 13:00 3.50 RIGU P PRE Spot the BOPE behind the well. Lay out Herculite around the Cellar. Back the Carrier over well slot MPK-33 with the Lead Operator (Pad Operator change out day), Well Site Leader and Toolpusher present. Jack and level the Carrier. 13:00 - 14:00 1.00 RIGU P PRE Hook up rig modules. Raise and scope Derrick 14:00 - 17:00 3.00 KILL P DECOMP Accept the rig. Rlg up Tiger Tank and circ lines to kill. Pressure test hardline to tiger tank to 500 psi. Test to closed choke to 3500 psi. 17:00 - 18:00 1.00 KILL P DECOMP R/U Lubric t r and to t t 0 si. Pull BPV. 20 si on tubin and 1,070 psi on IA. OA pressure 0 psi 18:00 - 19:00 1.00 KILL P DECOMP Bleed down IA pressure to 870 psi. Pump 120 degree seawater down tubing, lined up to take returns through the choke out to the Tiger Tank. Pump 55 bbls at 3 bpm with 70 psi. No returns. 19:00 - 22:30 3.50 KILL P DECOMP Bullhead 410 bbls of 120 degree seawater down the IA at 3 bpm with 100 psi. Line up and bullhead 55 bbls of 120 degree seawater down the tubing at 3 bpm with 80 psi. Shut down. IA and tubing both on a vac. 22:30 - 23:00 0.50 KILL P DECOMP Monitor well for 30 minutes both IA and tubin are on a vac. 23:00 - 00:00 1.00 KILL P DECOMP R/D well kill equipment 8/6/2008 00:00 - 00:30 0.50 KILL P DECOMP R/D well kill assembly. Check tubing and IA, both of a vac. 00:30 - 01:00 0.50 KILL P DECOMP P/U T-bar and install TWC with the FMC wellhead tech, and test from above to 3 500 si for 10 minutes on the chart. Good. test. 01:00 - 02:00 1.00 KILL P DECOMP Pressure was noticed building on IA, bleed off pressure and monitor welL.No ressure building on IA gauge, but could feel a little pressure coming from valve. Call well tech to pull TWC. 02:00 - 02:30 0.50 KILL P DECOMP bricator and test to 500 si. Pull TWC. Tubin was on a vac. 02:30 - 03:00 0.50 KILL P DECOMP R/U hose from IA to tubing and U-tube. Both tubing and IA static after 10 minutes. 03:00 - 03:30 0.50 KILL P DECOMP Monitor IA and tubing, both IA and tubing are static. 03:30 - 04:00 0.50 KILL P DECOMP P/U T-bar and_dry rod in the TWC with the FMC wellhead tech. Test from above to 3,500 psi for 10 minutes on the chart. Gooc 04:00 - 05:00 1.00 WHSUR P DECOMP ND tree and inspect hanger and hanger threads. Threads in good condition. Gravity feed in 35 bbls of seawater into IA. 05:00 - 09:00 4.00 BOPSU P DECOMP N/U DSA and BOP . 09:00 - 13:00 4.00 BOPSU P DECOMP John Crisp with AOGCC waived State's right to witness BOPE testing. Test all components to 250 psi / 3500 psi. Use 2 7/8" test joint. Koomey Drawdown test performed. 13:00 - 14:00 1.00 PULL P DECOMP RU Opso-Lopso. Install lubricator. Pull TWC. Tubing and IA on vacuum. Lay down lubricator, polish rod, Opso-Lopso. 14:00 - 15:00 1.00 PULL P DECOMP PUMU 3" LH Acme XO to 3 1/2" landing joint. Screw into hanger with 9 turns. BOLDS. Pull hanger into stack. Pulled free with 80K u ward strip wei ht.- Pump 60 Bbls of MPU Printed: 8/25/2008 2:09:07 PM • • BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPK-33 Common Well Name: MPK-33 Spud Date: 1/9/1997 Event Name: WORKOVER Start: 8/4/2008 End: 8/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/9/2008 Rig Name: NABOBS 3S Rig Number: and tubing hanger. 15:00 - 00:00 9.00 PULL P DECOMP For ten foot pup and 1st single of tubing, had to work pipe as was "sticky" off bottom. Work pipe to 110K PUW, and 35K SOW. Run cable over shieve. ,POH standing back 2-7/8" tubin Re ulate hole fill C~ 20 Bbl/Hr no returns . 8/7/2008 00:00 - 02:30 2.50 PULL P DECOMP POH standing back 2-7/8" tubing. Regulate hole fill ~ 20 Bbl/Hr (no returns). Recovered 288 joints 2-7/8" tubing, 1 XN nipple assembly, 2 GLM assemblies, 151 LaSalle clamps. 78 stands out there was an armour repair that was coming apart, on 110 stands out of hole recover 2 pieces of rubber between pipe and ESP cable, it appears to be from Kelly hose. Some Date From - To Hours ' Task 'Code NPT Phase Description of Operations 8/6/2008 14:00 - 15:00 1.00 PULL P DECOMP source water down tubing with no returns. BOLD landing joint 02:30 - 07:30 5.00 PULL P DECOMP L/D ESP assembly, cut cable and run over sheave. A little corrosion on ESP, bolts on ESP packed with scale and difficult to remove. 07:30 - 08:30 1.00 CLEAN P CLEAN Clean and clear rig floor. RD elephant trunk. Prep for cleanout run 08:30 - 09:30 1.00 CLEAN P CLEAN Slip and cut drill line. 09:30 - 14:30 5.00 CLEAN P CLEAN PUMU 6-1/8" bit, 7" Csg Scraper, XO's to 2-7/8" tubing. RIH 14:30 - 15:30 I 1.001 CLEAN I P 15:30 - 21:00 I 5.501 CLEAN I P 21:00 - 21:30 0.50 CLEAN P 21:30 - 23:00 1.50 ZONISO P 23:00 - 00:00 1.00 ZONISO P 8/8/2008 100:00 - 03:00 l 3.00 ZONISO 03:00 - 06:30 I 3.501 ZONISO 06:30 - 08:00 1.50 ZONISO 08:00 - 09:00 1.00 WHSUR 09:00 - 12:30 3.50 RUNCOI 12:30 - 19:30 7.00 RUNCOI 19:30 - 21:30 2.00 21:30 - 23:30 2.00 23:30 - 00:00 I 0.50 8/9/2008 100:00 - 00:30 I 0.50 CLEAN RIH w/ 7" Csg scraper - 141 stands and 18 singles to depth of 9445'. Maintain hole fill C~3 20 Bbls / Hr. Work scraper back thru CIBP settin de th C~? 9320' CLEAN POH lay down singles of 2-7/8" tubing. POH standing back tubing in Derrick. Maintain 20 Bbls / Hr hole fill. CLEAN B/O and L/D 7" casing scraper. CLEAN N/D flow riser and N/U shooting flange. CLEAN R/U SWS, lubricator, pump in sub, wireline BOP's, and pack-off. Maintain 20 bph hole fill. CLEAN R/U SWS, lubricator, pump in sub, wireline BOP's, and pack-off. M/U HES 7" CIBP. Test assembly. Maintain 20 bph hole fill CLEAN R1H with 7" HES CIBP, GR/CCL on SWS E-Line. Maintain 20 bph hole fill. RIH to 9400'. Tle in with original pert log and set ~, CIBP ~ 9320' MD POH w/ SLB setting tool CLEAN Rig down SLB equipment. RUNCMP ND shooting flange. NU riser. RUNCMP PUMU ESP as per Centrilift. Install zinc anode on bottom. RUNCMP RIH w/ ESP on 2-7/8" tubing. Check cable and flush pump every 2000', 600 psi ~ 1/2 BPM. RUNCMP Make cable to cable splice with 120 stands in hole RUNCMP Continue RIH with 141 stamds from the Derrick. PU singles and uppermost GLM with DPSOV. PU 4 singles and RIH. Continuous hole fill ~ 20 BI / Hr. RUNCMP While RIH with final single of 2-7/8 (joint # 288), BHA started to take weight. Slack off 10 K. Work pipe with UW of 110K and slacking off to 15 K on BHA. Work ESP to 9160'. Appear to be pushing something down hole. RUNCMP Work pipe with UW of 110K and putting 10K down BHA from 9140' - 9160'. Check conductivity of cable. OK. Lay down 2 singles of 2-7/8" tubing. Ran 286 jts, 2 GLMs, 1 XN. Installed Printed: S/25/2008 2:09:07 PM • • BP EXPLORATION Page 3 of 3 .operations. Summary Report Legal Well Name: MPK-33 Common Well Name: MPK-33 Spud Date: 1/9/1997 Event Name: WORKOVER Start: 8/4/2008 End: 8/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/9/2008 Rig Name: NABOBS 3S Rig Number: Date ~ From - To ~ Hours ~ Task Code NPT Phase Description of Operations 8/9/2008 00:00 - 00:30 0.50 BUNCO RUNCMP 151 LaSalle clamps, 3 Flat guards, 5 protectos, 1 zinc anode on bottom. 00:30 - 03:00 2.50 BUNCO RUNCMP PUMU hanger. Fill tubing with 8 Bls. Flush pump with 10 Bbls C~ 3/4 BPM, 1200 psi. Install penetrator, cut cable and make penetrator splice. Test cable - OK 03:00 - 04:00 1.00 BUNCO RUNCMP PUW of 92K, SOW of 50K. Land completion. BOLD landing joint. Set and Test TWC to 3500 psi. TnaTle to test from below due to well conditions. 04:00 - 08:00 4.00 BUNCO RUNCMP ND BOPE 08:00 - 10:30 2.50 BUNCO RUNCMP NU tree. Test hanger void to 5000 psi for 20 minutes. Centrilift final checks: 4.0 ohm phase to phase / 1 gig ohms phase to ground /BHP of 1538 psi / BHT of 147 deg F. Test tree to 5000 psi with diesel. 10:30 - 12:00 1.50 BUNCO RUNCMP PUMU lubricator. Test to 500 psi with diesel. Pull TWA 0 psi on WHP's. Dry Rod TWC. Normal up tree and cellar. Rig released ~ 12:00. Printed: 8/25/2008 2:09:07 PM Page L of 1 ~lllell: MPK-33 Well History Well Date Summary MPK-33 4/3/2008 RWO PREP *** WELL S/I ON ARRIVAL *** PULL 1"DGLV C~3 9039' MD (POCKET LEFT OPEN), PULL 1" DPSOV & SET 1" DGLV C~ 140' MD. RAN 2.07" CENT, SS, DUAL SPARTEK GAUGES, MAKE 30 MIN STOP @ 8661' MD. TAGGED ESP C~ 9161' SLM (3' CORK TO 9164' MD), MAKE 3 HOUR STOP C~3 9162' MD. ***WELL S/I ON DEPART*** **** NOTE**** BPV NEEDS TO BE SET MPK-33 7/25/2008 T/I/0=1250/1280/0. (Scale inhibitor treatment) Load IA w/ 201 bbls crude. Pump 10 bbls crude down tbg to ensure infectivity. Pumped 19.2 bbls EC6085A Scale Inhibitor and 172 bbls source water down tubing through filter pod. Pumped 173 bbls of Source water down tubing for over flush and displacement. Pumped 15 bbls Dead Crude down tubing for Freeze Protect. Well left shut in for RWO. FWHP= 0/1100/0 MPK-33 7/27/2008 The Well Support Techs rigged up and removed the wellhouse, flowlines and foundations. NOTE: A Back Pressure Valve will need set after the slickline work is completed. MPK-33 7/30/2008 ***ARRIV ON LOC WELL S/I*** PRE RIG MADE 30 MIN C~ 8664 TIME 04:45 TO :05:15 MADE3 HOURS STOP ~ 9179 TIME 05:45 TO 8:45 SET BPV ***TURN WELL OVER TO DSO *** MPK-33 8/7/2008 SET 1" BEK-DPSOV IN EMPTY MANDREL AND CHECKED MANDREL WITH DGLV ON RIG FLOOR OF 3S. DPSOV MANDREL FLAGGED AND TAGGED. MPK-33 8/10/2008 (Freeze Protect TBG and IA) T/I/0= 0/0/0 Pump 15 bbls dead crude down TBG followed by 65 bbls dead crude down IA to freeze protect well. FWHP= 0/0/0 Valve position =swab-closed /wing-closed / ssv-closed /master-closed / IA and OA open to gauges. MPK-33 8/15/2008 WEII Tech PT flow line to 1150 PSI for 10 min. with diesel, and then Pulled BPV. Print Date: 8/27/2008 Page 1 of 1 .. -..... ~ ¡'""\ STATE OF ALASKA ,~ ALASKA \..IlL AND GAS CONSERVATION COhlllll1lSSION REPORT OF SUNDRY WELL OPERATIONS ~ 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 61.10' 0 Suspend Da Repair Well Da Pull Tubing S. Property Designation: ADL 375132 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11543 9310 11341 9110 Casing Structural Conductor Surface Intermediate Production Liner Length 74' 6630' 11492' Perforation Depth MD (ft): Perforation Depth TVD (ft): 0 Operation Shutdown 0 Perforate 0 Plug Perforations 0 Stimulate 0 Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: II Development 0 Exploratory 0 Stratigraphic Test 0 Service 0 Waiver Da Other 0 Time Extension Change Out ESP 0 Annular Disposal 5. Permit To Drill Number 196-202 6. API Number: 50-029-22729-00 9. Well Name and Number: MPK.33 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands feet feet Plugs (measured) 11341' feet Junk (measured) N/A feet Size MD TVD Burst 20" 112' 112' 9-5/S" 6666' 494S' 5750 7" 11526' 9293' 7240 Collapse 3090 5410 2-7/S", 6.5# RECEIVED MAY 2 ð 2004 AJasIca 011 & Gas Con L-SO Anctr~ ~ 92S0' - 9334' 7070' - 7123' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: SCANNED JUN 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run II Daily Report of Well Operations H Well Schematic Diagram 0 9 1004 Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casino Pressure Tubino Pressure 15. Well Class after proposed work: 0 Exploratory II Development 0 Service 16. Well Status after proposed work: IS Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Si9~;~J¿~~ Form 10-404 Revised 12/2003 Title Technical Assistant Phone ''''5- 7 a '-( (Prepared By Name/Number: DataL) <:...c)"'\.: 564-4750 (' I) I G I t\ I A - \.) h I "l d\L I ØBDMSBfL JUN 0 3 'On!; , - r"'\ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-33 MPK-33 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/30/2004 Rig Release: 5/2/2004 Rig Number: 4ES Spud Date: 1/9/1997 End: 5/2/2004 4/30/2004 09:00 - 10:30 1.50 MOB P PRE Scope & lower derrick. 10:30 - 11 :30 1.00 MOB P PRE RID equip & prepare to move from MPF-57a to MPK-33. 11 :30 - 16:00 4.50 MOB P PRE Move rig sub & camp from MPF-57a to MPK-33. 12 miles. 16:00 - 17:30 1.50 MOB P PRE Lay herculite & matting boards. Spot in rig sub over MPK-33 wellhead. 17:30 - 19:00 1.50 RIGU P PRE Raise & scope up derrick. 19:00 - 20:00 1.00 RIGU P PRE Spot in camp, pipe shed & pits. 20:00 - 21 :30 1.50 WHSUR P DECOMP R/U lines to tree & tiger tank. Accepted well @ 2000 hrs. 21 :30 . 23:30 2.00 WHSUR P DECOMP P/U lubricator Pull BPV. Take on seawater as kill fluid in rig pits. Test kill lines to 3500 psi. 23:30 - 00:00 0.50 KILL P DECOMP Open well. SITP 1360 psi, SICP 1360 psi. Pump tubing volume 55 Bbls & bleed off casing pressure. 5/1/2004 00:00 - 02:30 2.50 KILL P DECOMP Continue to kill well. Max kill rate down tbg 4.5 BPM @ 1200 psi. Pumped tubing volume (54 bbls) Tubing on vacuum. Con't to bleed off annulus.. Pumped 30 bbls down annulus, 6 BPM @ 200 psi. Annulus went on vacuum. SID & monitor well. Well dead. 02:30 . 03:00 0.50 WHSUR P DECOMP P/U lubricator & install TWC. Test to 3500 psi. Blow down & Rig down lines to tree. UD lubricator. 03:00 - 04:00 1.00 WHSUR P DECOMP Bleed off hanger void & N/D X-mas tree. 04:00 - 06:30 2.50 WHSUR P DECOMP N/U BOPE. 06:30 - 09:00 2.50 BOPSUF P DECOMP PJSM. Conduct full test on all BOPE components, no failures. Witnessing of test waived by AOGCC rep John Spaulding. 09:00 - 10:00 1.00 BOPSUF P DECOMP PJSM. Drain stack, pull 2 way check. 10:00 - 10:30 0.50 PULL P DECOMP PJSM. Make up landing joint, BOLDs. 10:30.11 :30 1.00 PULL P DECOMP PJSM. Gas, (small amount), breaking out of annulus. Line up & pump 175 bbls down 2 7/8" x 7" annulus @ 4 bpm 180 psi. Well on vacuum. 11 :30 - 12:30 1.00 PULL P DECOMP PJSM. Pull hanger to floor. Hanger broke loose @ 90K, leveled out @ 80K up wt. UD hanger & rig up to pull ESP cable. 12:30 - 15:00 2.50 PULL P DECOMP PJSM. POOH w/2 7/8" tbg & ESP cable, triple displacement on hole fill. Pull 39 stands. 15:00 - 16:00 1.00 PULL P DECOMP Cut splice. Change out cable spools on spooler. 16:00 - 19:00 3.00 PULL P DECOMP Continue to POOH wI stands of 2 7/8" tubing. Pulled total of 96 stands. recovered 151 LaSalle Clamps, 4 Protectolizers & 2 flat guards. 19:00 - 21 :00 2.00 PULL P DECOMP UD ESP. Test same. ESP heavily scaled up. 21 :00 - 21 :30 0.50 PULL P DECOMP Clear & clean rig floor. Remove old ESP from floor. 21 :30 - 22:30 1.00 PULL P COMP Change out ESP cable spools in spooling unit. Load new ESP in pipe shed. 22:30 - 00:00 1.50 RUNCOIvP COMP P/U & M/U new ESP. Service & test same. 51212004 00:00 - 00:30 0.50 RUNCOIvP COMP Con't to service & test ESP. 00:30 - 03:30 3.00 RUNCOtvP COMP RIH wI ESP on 2 718" tbg. Test every 2000'. Pump thru pump every 2000'. 1 BPM @ 600 psi. 03:30 - 04:00 0.50 RUNCOIvP COMP Repair armored cable@ 4037'. Cut section of armor off. Install & solder on new piece of armor. 04:00 - 08:30 4.50 RUNCOIvP COMP Continue to RIH wI stands of 2 7/8" tubing. Test ESP & pump thru pump every 2000', WI 82 stands run meg & splice cable. 08:30 - 09:30 1.00 RUNCOtvP COMP Continue in hole wI 2 7/8" ESP completion. 09:30 - 10:00 0.50 RUNCOIvP COMP PJSM. Make up landing joint. 10:00 - 11 :30 1.50 RUNCOIvP COMP Make final field connection, cable to hanger, test same, OK. 11 :30 - 12:00 0.50 RUNCOIvP COMP PJSM. Up wt 85K, Down wt 50K. Land hanger. RILDs. 12:00 - 14:00 2.00 BOPSUP P COMP PJSM. Set two way check, N/D BOPE. Printed. 5/312004 8:45.26 AM SCANNED JUN 0 9 2004 ~.... .p r--- ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-33 MPK-33 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/30/2004 Rig Release: 5/2/2004 Rig Number: 4ES Spud Date: 1/9/1997 End: 5/2/2004 51212004 14:00 - 15:00 15:00 - 16:00 1.00 WHSUR P 1.00 WHSUR P COMP COMP PJSM. N/U tree. Test void & tree @ 5000 psi, OK. PJSM. Pull 2 way check valve, set BPV. Secure well. Rig released @ 16:00 hrs. Pnnted: 5/3/2004 8:45:26 AM SCANNED JUN 0 9 2004 " It " . TREE. 2.9/16" - 5M Cooper WELLHEAD:11"x 7-1/16" 5M FMr"\ 5A wl7"x 2-7/8" FMC Hanger wi 3" LH Acme Top, 2.5' CIW H BPV profile Conductor Casing I 112' 9 5/8" 40 ppf L-80 casing 6666' I ~ KOP @ 380' Max Hole Angle: 58° @ 3840' MD Angle thru perfs = ¡- Max DLS = 4.34° @ 7311' MD 27/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btrc. prod. casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ) Stimulation Summary Perforation Summary Ref log: GRlCCL 01/29/97 Size SPF Interval (TVD) 4.5" 5 9280 - 9306 7088'-7095' 33/8"' 4 9306 - 9316 7095'-7105' 33/8"' 4 9328 - 9334 7117'-7123' 'shot 6/27101 wi Schlumberger Power et guns 15 bbls, 75 sx "G" 15.8# cement Abandoned Sag River Perforations: Size SPF Interval (TVD) 4.5" 11374'-11394' 9143'.9162' 5 DATE REV. BY MPK-33 A U D - INm~Nh~ COMMENTS 02/13/97 02/24/98 04/02/99 06/29/01 05/01/04 MOO M. Under ESP Completion 4-ES RWO 5-S Orig~ Elev. = 61.8 (N27E) Oriç, . Elev. = 27.8 (N27E) Orig. KB to BF = 19.8 (N4ES) Camco 2-7/8" x 1" I sidepocket KBMM GLM 140' Camco 2-7/8" x 1" sidepocket KBMM GLM I 9039' I I 9150' I 9164' I 2-7/8" XN nipple (10 2.205") Pump, 151 stg. GC1700 I with Tungsten Carbide stages, Model- GPMTAR 1:1 Intake 9,181' MD = 6,971' TVD Tandem Gas Separator I 9181' GRSXTBAR H6 I Tandem Seal Section I 918 I GSB3 DB UT/LT IL H6 (PFS)Ab HSN 6' Motor, 140 HP, 2444 volt, I 9200' I 37 amp, Model KMH-A PumpMate w/6 fin Centralizer I 9217' I 7" HES Bridge Plug I 11341' ( ') ~ :z z m 0 Co- c ::z <::::- et:J '" c::> C) ..þ. 7" float collar (PBTD) 7" 26 ppf L-80 BTRS I 11483' I I 11525' I MILNE POINT UNft WELL K-33 API NO: 50-029-22129 JWS Conversion from Sad River to Kuparuk 4ES B. Hasebe RWO Nabors 4ES Lee Hulm~. RWO Nabors 4-ES BP EXPLORATION (AK) ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 64' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3537' NSL, 2056' WEL, SEC. 03, T12N, R11E, UM MPK-33 At top of productive interval 9. Permit Number / Approval No. 196-202 399-045 7' SNL, 1543' EWL, SEC. 11, T12N, R11E, UM 10. APl Number At effective depth 50-029-22729 217' SNL, 1749' EWL, SEC. 11, T12N, R11E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 235' SNL, 1773' EWL, SEC. 11, T12N, R11E, UM Sands 12. Present well condition summary Total depth: measured 11543 feet Plugs (measured) true vertical 9310 feet Effective depth: measured 11341 feet Junk (measured) true vertical 9110 feet Casing Length Size Cemented MD TVD Structural Conductor 74' 20" 250 sx Arcticset I 112' 112' Surface 6630' 9-5/8" 1950 sx PF 'E', 290 sx Class 'G' 6666' 4948' Intermediate Production 11492' 7" 550 sx Class 'G' 11526' 9293' Liner Perforation depth: measured Open: 9280' - 9306', 9306'- 9316', 9328'- 9334' Below Bridge Plug: 11374' - 11394' RECEIVED true vertical Open: 7070' - 7096', 7096' - 7106', 7117' - 7123' Below Bridge Plug: 9142'- 9162' JUL 2 7 2001 Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to 9213' Alaska Oil & Gas COns. Commis$[(~n Packers and SSSV (type and measured depth) None ~ch0rage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the4~,egoing is true ariel correct to the best of my knowledge Signed Sond~r~Stewm~''~~~~'~ Title Technical Assistant Date ~--~"-{ - '~ ~-t._~ '~ r~. ~",t ~ (,~ ~ ~ ! j~ ~ Prepared ByNarne/Number: Sondra Stewman, 564-4750 - iB~PLORATION Page 1 of 1 _ _ - _ mmaryReport Legal Well Name: MPK-33 Common Well Name: MPK-33 Spud Date: 1/9/1997 Event Name: WORKOVER Start: 6/22/2001 End: 6/28/2001 Contractor Name: NABORS Rig Release: 6/28/2001 Rig Name: NABORS 4ES Rig Number: · i Hours Activity Code-NPT ~phase Operations ~ .... ~! ........................ ~ -'~-'~ .... :~,~ ~_-~ :: ti Description of 612512001 21:00 - 00:00 3.00 MOB PRE RIG DOWN & REPAIR SCOPING BEAM & RE-INSTALL SAME. 6/26/2001 00:00 - 06:00 6.00 MOB PRE MI/RU/RAISE & SCOPE DERRICK & SAFE OUT RIG ACCEPT @ 0600 HRS. 612612001 06:00 - 09:30 3.50 KILL DECOMP RIG UP TREE TO TIGER TANK/TANK ON SEAWATER/RIG LINES & TEST TO 3500 PSI. & PULL BPV HOLD WELL KILL MEETING 09:30 - 11:30 2.00 KILL DECOMP CIRC WELL BORE INFLUX OUT WITH 8.5 PPG. SEAWATER. 11:30 - 13:00 1.50 WHSUR DEOOMP SET TWC & NIPPLE DN TREE 13:00- 15:30 2.50 BOPSUF DECOMP NIPPLE UP BOP 15:30 - 20:00 4.50 BOPSUF DECOMP TEST BOP TO 350 LOW & 3500 HIGH TEST WITNESSED BY LEW GRIMMALDI WITH ACCO 20:00 - 00:00 4.00 PULL DEGOMP RIG UP & PULL HANGER TO FLOOR &LAY DN SAME & STAR PULLING COMP. 6/27/2001 00:00 - 10:00 10.00 PULL P DECOMP CONTINUE TO POOH W/COMPLETION & LAY DN ESP ASSY & CAVlNS DESANDER & TAILPIPE & EVALUATE SAME. 10:00 - 15:00 5.00 PERF ~ COMP SAFETY MEETING/RIG SWS & RIH WITH 30' GUN LOADED WITH 10' ON TOP & 6' ON BOTFOM & LOG INTO POSITION & PERFORATE INTERVALS 9306'--9316' & 9328'--9334' & POOH LAY DN SAME & RIG DN SWS. 15:00 - 00:00 9.00 RUNCOI~!~ COMP MU ESP ASSY/& RIH WITH SAME MAKING MID-LINE SPLICE 6/28/2001 00:00 - 08:00 8.00 BOPSUR P COMP NIPPLE DN BOP 08:00 - 10:00 2.00 WHSUR P COMP NIPPLE UP TREE. & TEST TO 5000 PSI. 10:00 - 12:00 2.00 PULL P COMP RIG LUBRICATOR & PULL TWC & SET BPV. & SECURE TREE AREA. AND RELEASE RIG AT @ 1200 HRS. 6/28/2001 Printed: 7/2/2001 11:28:04 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN~O~ 1. Status of Well Classification of Service V~f~Ji~':'?~i]J~:~.,'j-~ [] Oil r-] Gas [] Suspended [] Abandoned [-] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 96-202 399-045 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22729 4. Location of well at surface ..~ :..-. . -~.: - , ~:..~,,~.~,~,,,~_~¢ 9. Unit or Lease Name 3537' NSL, 2056' WEL, SEC. 03, T12N, R11 E, UM :-':-' · ": :":~':~. ~'~'~' '~j:~-` ~ f Milne Point Unit of ~productive interval :, ~/j~[~.~ 10. Well Number At tota, depth t_ ~i~-~-i i_~_ .; ?}~~i 11. Field and Pool 235' SNL, 1773' EWL, SEC. 11, T12N, R11E, UM ' Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 64'I ADL 375132 12. Date Spudded1/9/97 J 13' Date T'D' Reached J 14' Date C°mp" Susp" °r Aband'J 15' Water depth' if °ffsh°re 116' N°' °f C°mpleti°nsl/22/97 3/30~99 N/A MSL One 17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121 . Thickness of Permafrost 11543 9310 FTJ 11484 9251 FTJ [~Yes ~lNo N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, EMSS, GR/CCL 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTI'OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 # H-40 38' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 36' 6666' 12-1/4" 1950 sx PF 'E', 290 sx 'G', 100 sx PF 'C' 7" 26# L-80 34' 11526' 8-1/2" [550 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 2-7/8", 6.5#, L-80 9609' N/A MD TVD MD TVD 9280' - 9306' 7070' - 7096' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11341' 7" HES BP w/15 Bbls Class 'G' Cmt on top Freeze Protect with 12 Bbls of Diesel Date First Production I Method of Operation (Flowing, gas lift, etc.) April 9, 1999I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. (subsea) Top Kuparuk C 9277' 7006' Top KC1 9279' 7008' Top Kuparuk B7 9316' 7045' Top Kuparuk 'A' 9522' 7248' Top Shublik 11406' 9113' 31. List of Attachments Summary of Daily Drilling Reports 32. I hereby certify that the fore, e~oing is true and correct to the best of my knowledge s, ned- Terrie Hubble ~'//~//),~'j~ Title Technical Assistant III Date ~ ' MPK-33 96-202 399-045 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1.' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility M Pt K Pad Progress Report Well MPK-33 Page 1 Rig ~q;g~ ~~ (4~ Date 14 April 99 Date/Time 25 Mar 99 26 Mar 99 27 Mar 99 28 Mar 99 29 Mar 99 30 Mar 99 16:00-03:00 03:00-06:00 06:00-10:00 10:00-14:00 14:00-16:00 16:00-21:00 21:00-02:00 02:00-03:30 03:30-04:30 04:30-06:00 06:00-07:00 07:00-09:30 09:30-10:00 10:00-11:30 11:30-22:00 22:00-23:30 23:30-01:00 01:00-06:00 06:00-14:30 14:30-19:00 19:00-20:00 20:00-21:30 21:30-22:00 22:00-23:00 23:00-02:30 02:30-06:00 06:00-09:30 09:30-10:30 10:30-16:00 16:00-19:00 19:00-20:00 20:00-01:00 01:00-06:00 06:00-07:00 07:00-09:30 09:30-10:00 10:00-12:30 12:30-13:30 13:30-15:00 15:00-18:00 Duration llhr 3hr 4hr 4hr 2hr 5hr 5hr 1-1/2 hr lhr 1-1/2 hr lhr 2-1/2 hr 1/2hr 1-1/2 hr 10-1/2 hr 1-1/2 hr 1-1/2 hr 5hr 8-1/2 hr 4-1/2 hr lhr 1-1/2 hr 1/2 hr lhr 3-1/2 hr 3-1/2 hr 3-1/2 hr lhr 5-1/2 hr 3hr lhr 5hr 5hr lhr 2-1/2 hr 1/2 hr 2-1/2 hr lhr 1-1/2 hr 3hr Activity Rig moved 100.00 % Installed High pressure lines Tested High pressure lines Bullhead well Bullhead well Bleed down well Conducted slickline operations on Slickline equipment - Retrival run Bullhead well Installed Hanger plug Installed BOP stack Installed BOP stack Tested BOP stack Removed Hanger plug Retrieved Tubing hanger Pulled Tubing in stands to 90.00 ft Rigged down sub-surface equipment - ESP Rigged up Drillstring handling equipment Ran Drillpipe to 3125.00 ft (3-1/2in OD) Ran Drillpipe to 11366.00 ft (3-1/2in OD) Conducted electric cable operations Set packer at 11341.00 ft with 0.0 psi Batch mixed slurry - 15.000 bbl Pulled Drillpipe in stands to 10411.00 ft Reverse circulated at 10411.00 ft Circulated at 10411.00 ft Laid down 6653.00 ft of 3-1/2in OD drill pipe Laid down 3697.00 ft of 3-1/2in OD drill pipe Worked on BOP - Lubricator Perforated from 9280.00 ft to 9306.00 ft Conducted electric cable operations Worked on BOP - Lubricator Rigged up sub-surface equipment - ESP Ran Tubing in stands to 6200.00 ft Ran Tubing in stands to 9609.00 ft Serviced Completion equipment Ran Tubing in stands to 9609.00 ft Installed Tubing hanger Removed BOP stack Installed Xmas tree Freeze protect well - 12.000 bbl of Diesel ~ -" STATE OF ALASKA ALASKA O,._ AND GAS CONSERVATION COMN,,$SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate ' [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Change to Kuparuk C Prod. 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3537' NSL, 2056' WEL, SEC. 03, T12N, R11E, UM At top of productive interval 223' SNL, 1762' EWL, SEC. 11, T12N, R11E, UM At effective depth 229' SNL, 1768' EWL, SEC. 11, T12N, R11E, UM At total depth 235' SNL, 1773' EWL, SEC. 11, T12N, R11E, UM 5. Type of well: [] Development [~ Exploratory [~] Stratigraphic [-q Service 6. Datum Elevation (DF or KB) KBE = 64' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-33 9. Permit Number 96-202 10. APl Number 50-029-22729 1. Field and Pool Milne Point Unit / Sag River Sands 12. Present well condition summary Total depth: measured 11543 feet true vertical 9310 feet Effective depth: measured 11484 feet true vertical 9251 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 74' 20" 6630' 9-5/8" 11492' 7" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I 1950 sx PF 'E', 290 sx Class 'G' 550 sx Class 'G' MD TVD 112' 112' 6666' 4948' 11526' 9293' Perforation depth: measured 11374' - 11394' true vertical 9142' - 9162' ORIGINAL Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to 11210' Packers and SSSV (type and measured depth) None 13. Attachments [~ Description summary of proposal 14. Estimated date for commencing operation March 18, 1999 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Robert Laule, 564-5195 Date approved [~] Detailed operations program i--I BOP sketch I15. Status of well classifications as: [] Oil l--I Gas F-~ Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~, ~,/~. ~~ Terrie Hubble Title Technical Assistant III Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity / BOP Test c,,'" Location clearance Mechanical Integrity Test Subsequent form re~idi'¢~ 1'0- ,. ORIGINAL SIGNED BY Approved by order of the Commission Rebed; N. Ohristenson i~/:7~/~?~ Commissioner Form 10-403 Rev. 06/15/88 I Approval No.J~F--~. ~ Date ',-~"'-/ ~--F~// Submit In Triplicate . leare.d rvices rilling To: Alaska Oil & Gas Conservation Commission Date: March 16, 1999 From: Subject: Robert Laule Operations Drilling Engineer MPK-13, 50-029-22729 PLANNED SCOPE OF WORK: 1. MIRU 2. Pull the BPV with a lubricator. 3. Circulate well with kill weight fluid 4. Pull the existing ESP completion. 5. Suspend the Sag River interval with a bridge plug set and tested at 11,350. A 15 bbl balanced cement plug placed above the BP. 6. Change over to 9.3 ppg brine 7. Perforate the Kuparuk from 9280-9306 with 4.5" 5 SPF 8. GR/LB run to below completion setting depth 9. RIH with new FC650 ESP assembly on 2-7/8" tubing. The tracker will be set at 9212' MD with desander and mud anchor. TREE: 2-9/16"-5M Cooper MPU K 33 Orig. KB Lie J1.8 (N27E) WELLHEAD:11"x 7-1/16" 5M FMC Gen 5A ' Orig. GL Elev.: 27.8 (N27E) w/7"x 2-7/8" FMC Hanger w/3" LH Acme OriCl. KB to BF = 19.8 (N4ES) Top, 2.5" CIW H BPV profile Conductor Casing~ :""ii Iii sidepocket KBMM GLM KOP @ 380' Max Hole Angle: 58° @ 3840' MD Angle thru perfs = 7° Max DLS = 4.34° @ 7311' MD i 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. 2-7/8" HES XN nipple I 11162, ( drift ID = 2.347", cap. = 0.00592 bpf ) W/2.205" ID. 7" 26 ppf, L-80, Btrc. prod. casing ( drift ID = 6.151" cap. = 0.0383 bpf ) Centrilift FC-650 ESP, series513, FPMTARC 1:5,. 11173' 143 St_q. Gas separator I 11184' I Stimulation Summary Centrilift GRSTXBARH6 02/05/97 - 134 M# of 20-40 Carbolite behind seal section 11189' pipe. Flush to design. Centrilift KMHG 562 series, 57 hp motor, 1315 v./26 Perforation Summary ~ amps. Ref log: GPJCCL 01129197 4.5" 6 11374'-11394' 9143'-9162' 7" float collar (PBTD) [ 11,484' J 7" 26 ppf L-80 BTRS [ 11,526' J DATE REV. BY COMMENTS MILNE POINT UNIT 02/07/97 MDO 3ased hole completion 27E WELL K-33 02/13/97 MDO ESP Completion 4-ES APl NO: 50-029-22729 02/24/98 M. Linder RWO 5-S BP EXPLORATION (AK) "~ STATE OF ALASKA - ALASKA O,_ AND GAS CONSERVATION COM~,.,$SION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon ~Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Recompletion 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3537' NSL, 2056' WEL, SEC. 3, T12N, R11 E, UM At top of productive interval 223' SNL, 1762' EWL, SEC. 11, T12N, R11E, UM At effective depth 229' SNL, 1768' EWL, SEC. 11, T12N, R11E, UM At total depth 235' SNL, 1773' EWL, SEC. 11, T12N, R11 E, UM 5. Type of well: [~ Development [--I Exploratory r-I Stratigraphic [-I Service 6. Datum Elevation (DF or KB) KBE=64' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-33 9. Permit Number 96-202 10. APl Number 50-029-22729 11. Field and Pool Milne Point Unit / Sag River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11543 feet 9310 feet 11484 feet 9251 feet Length Size 74' 20" 6630' 9-5/8" 11492' 7" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset 1 1950 sx PF 'E', 290 sx 'G' 550 sx Class 'G' MD TVD 112' 112' 6666' 4920' 11526' 9266' Perforation depth: measured 11374'-11394' true vertical ~ Tubing (size, grade, and measured depth) ORIGINAL 2-7/8" 6.5 ppf, L-80 8rd EUE tubing to 11173' Packers and SSSV (type and measured depth) 13. Attachments [~ Description summary of proposal I~ Detailed operations program [--1 BOP sketch 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classifications as: [~ Oil E~ Gas E~] Suspended Service Contact Engineer Name/Number: Angela Sorrentino, 564-5943 Prepared By Name/Number: Michael Williams 564-4657 17. I hereby certify that the f_oregoing is ~. ~/'~. ~/; ~ true ~d correct to the best of my knowledge Signed AngelaSorrentino {¢/t~/V'~','.;--~- ~~~' Title SurveillanceEnqineer Jf ' Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness ]Approval No. Plug integrity ~ BOP Test ~ Location clearance __ o,,~e~ OOgxj Mechanical Integrity Test__ Subsequent form required 10- '?,e~ ~.-~¢t¢ I_~ .... ORIGINAL SIGNED-BY Approved b)L.or-de'Fof the Commission -~obert N. Chdstenson Commissioner Date~'"~/¢, '-~'~ Forrml'O-~03 Rev. 06/15/88 Submit In Triplicate Well MPK-33 Suspension of Sag and Completion of Kuparuk Well MPK-33, was drilled and completed as a Sag River producer in 1/97 by 27E. The Sag River was frac'd with 137M# of 20/40 proppant in 2/97 providing initial production at 500 bopd. The rate quickly dropped to 200 bopd due to the lack of pressure support as the pressure dropped below bubble point. There have been two pumps in the well which lasted 283 and 41 days respectively. Currently it is not economically feasible to workover the well for additional Sag production. It has been decided to plug the Sag River completion in K-33 and re-complete as a Kupamk C sand producer. The pressure ~ the K-33 Sag is 3076 psi at 8930' tvd. The pressure in the Kuparuck is estimated to be 3450 psi at 7070' tvd. The current PBTD is 11,483' MD. In order to isolate the Sag interval, a 7" bridge plug will be placed no more than 50' above the top of the perforated interval from 11374'-11394' MD with a minimum of 75' of cement on top of the bridge plug. Perforations will be shot across the Kuparuk C sands from 9280' - 9306' MD. This work should be completed by the end of the 1Q 1999. The well is presently shut in and freeze protected. A 10-404 will be submitted after the workover is completed. 02/23/99 11:53 ~X 907 564 4995 BP INFO RES~_.<CE CTR TF F.E: 2-9/16"-5M Cooper MPU K-33 W~HEAD:11'x 7-1~6" ~ FMC Gen 5~ ' ~ ~ ' ' Oflg. GL Elev. ~ 27.8 (N27E) w/~[ 2-7~" ~C Han~er w/3" LH A~e ) Camco 2 7~' x 1 sidep~e, KBMM GLM I KO~ ~ ~0~ M~ H~e ~: 58~ ~ ~40' MD M~ DLS = 4.~° ~ ~11' MD Cam~ 2 7R' x 1' I sldepo~et ~MM Gm I 11,,4' ( d~ ID = 2.347', ~. = 0.~592 bpf ) w/2.205' ID. ;.7" 26 ~f, L-80, ~. prod. ~sing ::( d~ ID = 6.151, ~. = 0.0383 bpf) Cen~lR FC-~0 ESP. I 11173' series 513, FP~ARC 1:5, 143 Stg. Stimulation Summa~ ~ntrilifl GRS~BARH6 ' ~ 0~5~7 - 134 M~ ~ ~0 Ca~ol~e behi~ seal se~on ~ 11189' ~. Flush to d~n. Centdl~ ~HG 562 sedea, . 57hpmotor, 1315v./26 ~ 11~2' Perforation Summa~ amps. Ref Io~: G~CCL 01~7 Centdliff PHD [ 11210' I 4.5" ~ 11374'-113~' 9143'-9162' ., , 7" float ~llar (PBTD} r ~ .~ ~-~ ~.s I ~.~' I . ,... .... DATE R~. BY COMMAS MILNE POINT UN~ 0~7~7 . M~ Cased hole eomple~ 27E 02/13~7 . M~ ESP Completion ~E9 WELL K-33 0~24~8 M. U~r RWO BP EXPLORATION (A~ a ii i II PERMIT DATA AOGCC Individual Well Geologlcal Materials Inventory T DATA PLUS Page: 1 Date: 01/21/99 RLrN RECVD 96-202 96-202 96-202 96-202 96-202 96-202 96-202 96-202 96-202 96-202 96-202 B~ SET ~'~700-~0S~0 ST~ ~E~ ~ESS ~ ~4 GR/CCL DEPTH ~'6520-11449 7658 ~SCHLUM GR/CCL DGR/CNP/SLD-MD ~/318-11543 DGR/CNP/SLD-TVD ~318-9310 DGR/RES-TVD ~/318-9310 7664 ~ERR¥ MPT/GRC/aES/CNP/P~OB ~LTI SHOT ~PER~Y 6594.06-11310.38 M~ SR~ ~EaRM 0-~0543 FINAL 02/21/97 FINAL 02/21/97 FINAL 02/21/97 1 04/21/97 FINAL 04/30/97 FINAL 04/30/97 FINAL 04/30/97 FINAL 04/30/97 1-4 05/07/97 06/30/97 06/30/97 10-407 ~R~ COMPLETION DATE 2 I /ll9~/ DAILM WELL OPS a I / %'?'??/ TO ~11~-I~?1 Are dry ditch samples required? yes ~And received? Was the well cored? yes ~,~Analysis & description received? Are well tests required? yes ~_~,~.~Received? y~ Well is in compliance Initial COMMENTS ye~' BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO Box 196612 Anchorage, Alaska 99519-6612 Facsimile WESTERN NORTH SLOPE ASSET TO.' Name: Location: FROM: NOTES: PAGES TO FOLLOW: 2 DEC (Does Not Include Oover Sheet) SECURITY CLASSIFICATION PRIVATE Facsimile #: (907) 564-4440 Confirm if: (907) $64-4322 Orig. GL FJev, = ~7,6 (N27E) ~v17'x2.718' FMC Hangerwl3' LH Acme ~ -- - Ot~. K~ ~ BF= 19,8 (N4~) To~. 2.S" C~ H B~ pmfi~ dd~kat KBMM GLM *5/~'40ppfL~0~ng ~ i i) ~m~ 2 7/a"x 1" s~ep~ket K6MM GLM 2 WS" 6,5 ppf, L~0, 8 ( d~ ID ~ 2.~?', ~p. 7" 26 ppi, L-80, ~t~, prod, ~s~ng ( dd~ ID ~ 6,151", ~p, =.9.0383 bpi) ~liE F~0 ESP, ~es 513, FP~C ~tim~la~on~umma~ Cen~IR GES~H6 ~7-1~ ~ of2~0 ~]ite be~d p~, Flush to design. Cen~ P G~C~L - I ~ _, . ~' fl~ ~l~r (PB~)~~ -- Il J I I DATE R~. BY COMME~S - 0~07~ -' MDO }C~hol~ ~m~t~on 27E - MI~E POI~ U~T ...... ~LL -~1~ '* ~DO- ESP Complan ~ES APl NO: _S0~29-227.29 - . BP ~PLO~TION (AK) ~ I IL ,. IHIOd '~N-]IH NOIIU~JO-]HX3 'd'8. Nagq:PO 86, 80 GAP]: 1.50 0.6 V/V 0 35 BP ~ RHOBC Po:t'o~:l, 10 0 1 . 6 $ G/C3 :~ . 65 ~* Bw .... 0, O~ORi~ Sw .... So 0 0.~)~BP i~)DKr?..;00C 100 · · COR~ ~ Sw .... So O' O.OJ~m'' C~C)P.J~ %000 9.0 · ~ · lO0 I--I 0t, 16 '1' ~'N~KINIOd ~t N'I[I/~ I dwnd Jedel ~llplUOO ', giON 'uOI;ap o'~ t~nL, I 'a.. S 01~1n IlS ( idq CBCO'O '" 'dee:, ',,L~;I.'B - {3~ '~II;P ) ~ Oulla3Og,'~ldrlOl'.~/O 6 ndVM STATE OF ALASKA .... , ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Pull Tubing []Operation Shutdown [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage. Alaska 99519-6612 [] Plugging [] Perforate 4. Location of well at surface 3537' NSL, 2056' WEL, SEC. 3, T12N, R11 E, UM At top of productive interval 223' SNL, 1762' EWL, SEC. 11, T12N, R11E, UM At effective depth 229' SNL, 1768' EWL, SEC. 11, T12N, R11E, UM At total depth 235' SNL, 1773' EWL, SEC. 11, T12N, R11E, UM []Alter Casing [] Repair Well [] Other 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service ESP Replacement 6. Datum Elevation (DF or KB) KBE = 64' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-33 9. Permit Number / 96-202 Approval No. 10. APl Number 50- 029-22729 11. Field and Pool Milne Point Unit / Sag River Sands 12. Present well condition summary Total depth: measured 11543 feet true vertical 9310 feet Effective depth: measured 11484 feet true vertical 9251 feet Casing Length Size Structural Conductor 74' 20" Surface 6630' 9 5/8" Intermediate Production 11492' 7" Liner Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I 1950 sx PF 'E', 290 sx 'G' 100 sx PF 'C' 550 sx Class 'G' MD TVD 112' 112' 6666' 4920' 11526' 9266' Perforation depth: measured true vertical 11374' - 11394' (Subsea) 9081'- 9101' ORiGiNAL Tubing (size, grade, and measured depth) 2 7/8" 6.5 ppf, L-80 8rd EUE tubing to 11173' Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Et EIVEU Alaska 0ii & Gas Cons. O0mmissi0r~ Anchorage 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Cgpies of Logs and Surveys run i--q'D~aily Report of Well Operations 16. Status of well classifications as: ~-]Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,.Je~ne L. Haas -Title Staff Technical Assistant Prepared By Name/Number: Date ,-~ Jeanne L, Haas, 564-5225 Form 10-404 Rev. 06/15/88 Submit In Duplicate Facility M Pt K Pad Progress Report Well MPK-33 Page 1 Rig Nabors 5S Date 05 March 98 Date/Time 21 Feb 98 22 Feb 98 23 Feb 98 24 Feb 98 25 Feb 98 06:00-06:30 06:30-11:00 11:00-18:00 18:00-18:30 18:30-20:00 20:00-02:00 02:00-03:30 03:30-05:00 05:00-06:00 06:00-10:00 10:00-16:30 16:30-19:30 19:30-22:30 22:30-01:00 01:00-06:00 06:00-12:00 12:00-15:30 15:30-16:30 16:30-02:30 02:30-05:00 05:00-06:00 06:00-06:30 06:30-08:30 08:30-13:30 13:30-15:00 15:00-18:00 18:00-22:30 22:30-00:00 00:00-06:00 Duration 1/2 hr 4-1/2 hr 7 hr 1/2 hr 1-1/2 hr 6 hr 1-1/2 hr 1-1/2 hr 1 hr 4 hr 6-1/2 hr 3 hr 3 hr 2-1/2 hr 5 hr 6 hr 3-1/2 hr 1 hr 10hr 2-1/2 hr 1 hr 1/2 hr 2 hr 5 hr 1-1/2 hr 3 hr 4-1/2 hr 1-1/2 hr 6 hr Activity Held safety meeting Rig moved 100.00 % Rigged up Drillfloor / Derrick Held safety meeting Filter Brine Circulated at 11174.0 ft Rig waited: Materials Circulated at 11174.0 ft Bullhead well Removed Xmas tree Installed BOP stack Rigged down Hanger plug Serviced Drillfloor / Derrick Retrieved Tubing hanger Pulled Tubing in stands to 5900.0 ft Pulled Tubing in stands to 0.0 ft Conducted slickline operations on Slickline equipment - Tool run Rigged up sub-surface equipment - ESP Ran Tubing in stands to 7650.0 ft Installed ESP Ran Tubing in stands to 8500.0 ft Held safety meeting Ran Tubing in stands to 11210.0 ft Rigged up Tubing hanger Removed BOP stack Installed Xmas tree Displace treatment Backflow Rigged down Drillfloor / Derrick ~jaska~'' 0~ ;~ Gas Cons. Commission ,4nch0ra~e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [--I Gas [] Suspended I~ Abandoned [--I Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 96-202 396-243 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22729 4. Location of well at surface ..,,,.~..~m~ 9. Unit or Lease Name 3537' NSL, 2056' WEL, SEC. 3, T12N, R11E, UM i' ?;,...' i ~ Milne Point Unit At tOPsNL,Of productiVeEWL,interval 1, 'J ........=/---'~-¢2-'/J~'/¥~'~ !i i~!:~' 10. Well Number 223' 1762' SEC. 1 T12N, R11E, UM i MPK-33 Attotal depth ~ VERiFi~9 I~ 11. Field and Pool , - 235' SNL, 1773' EWL, SEC. 11, T12N, R11E, UM ~ .... ~__~._..~ .,,,.,,,,,,,,,.~ Milne Point Unit/Sag River Sands 5. Elevation in feet (indicate KB, DF, etc.) 16. Leash Designation'and Serial No. KBE = 64'I ADL 375132 12. Date Spudded1/9/97 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Abandl15' Water depth' if °fish°re I 16' N°' °f c°mpleti°nsl/22/97 2/11/97 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 11543 9310 FTI 11484 9251 FTI []Yes I--INoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, EMSS, GR/CCL 23. CASING, LINER AND CEMENTING RECORD CASING S E~-I-ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 # H-40 38' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 36' 6666' 12-1/4" 1950 sx PF 'E', 290 sx 'G', 100 sx PF 'C' 7" 26# L-80 34' 11526' 8-1/2" 550 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 6 spf 2-7/8", 6.5#, L-80 11236' N/A MD TVD MD TVD 11374'-11394' 9142'-9162' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 80 bbls diesel Frac pac, 11374'-11394' 134000# 20/40 Carbolite behind pipe 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) February 15, 1997 I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ! Flow Tubing Casing Pressure CALCULATED iOIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RE E V D Ir',] 5 0 ]99"/ Form 10-407 Rev. 07-01-80 nRlfilklAI S u b.Ji,~l~~icate .,. 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids Depth Depth recovered and gravity, GOR, and time of each phase. (subsea) Top KC1 9279' 7008' Top Kuparuk B7 9329' 7057' Top Kuparuk 'A' 9534' 7260' Top Shublik 11418' 9126' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the fo. regoing is ~ue and correct to the best of my knowledge Signed ~ ~.~?~. I~T /-"~./ ~/~ TimSchofield , ....- T, S~,~ itle Senior Drilling Engineer Date ,~.. .~ MPK-33 96-202 396-243 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 da .50 1997 j' ?~ . Alas__k_'a .Oit .& Gas Cons, Oom~tss~, ~n~horage Facility Date/Time 05 Jan 97 06 Jan 97 07 Jan 97 08 Jan 97 09 Jan 97 10 Jan 97 11 Jan 97 12 Jan 97 13 Jan 97 M Pt K Pad Progress Report Well MPK-33 Rig Page Date 17:01-06:00 06:00-06:00 06:00-18:00 18:00-18:30 18:30-02:00 02:00-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-15:30 15:30-16:30 16:30-18:00 18:00-18:30 18:30-21:00 21:00-02:00 02:00-06:00 06:00-06:30 06:30-07:30 07:30-01:30 01:30-02:30 02:30-06:00 06:00-06:30 06:30-07:00 07:00-14:00 14:00-14:30 14:30-18:00 18:00-18:30 18:30-21:00 21:00-22:00 22:00-23:30 23:30-00:30 00:30-01:30 01:30-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-14:30 14:30-16:30 16:30-19:00 19:00-23:30 23:30-01:00 01:00-03:00 03:00-06:00 06:00-06:30 06:30-02:00 02:00-03:00 03:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-10:00 10:00-13:00 13:00-16:00 16:00-19:00 Duration 12-3/4 hr 24 hr 12hr 1/2 hr 7-1/2 hr 2-1/2 hr lhr 1/2 hr 1/2 hr 9hr 1 hr 1-1/2 hr 1/2 hr 2-1/2 hr 5 hr 4 hr 1/2 hr lhr 18hr lhr 3-1/2 hr 1/2 hr 1/2 hr 7hr 1/2 hr 3-1/2 hr 1/2 hr 2-1/2 hr lhr 1-1/2 hr lhr lhr 2 hr 1 hr 1-1/2 hr 1/2 hr 8hr 2hr 2-1/2 hr 4-1/2 hr 1-1/2 hr 2hr 3hr 1/2 hr 19-1/2 hr 1 hr 2-1/2 hr 1/2 hr 1/2 hr 1 hr 2-1/2 hr 3hr 3hr 3hr Activity Rig moved 0.00 % Rig moved 80.00 % Commissioned Drillfloor / Derrick Held safety meeting Rigged up Divertor Pulled Drillpipe in stands to 0.0 ft Repaired Main engine Performed formation integrity test Held safety meeting Ran Drillpipe in stands to 0.0 ft Fill pits with Water based mud Made up BHA no. 1 Held safety meeting Repaired Fluid system Repaired Fluid system Drilled to 320.0 ft Held safety meeting Made up BHA no. 1 Drilled to 2029.0 ft Circulated at 2029.0 ft Pulled out of hole to 225.0 ft Held safety meeting R.I.H. to 2029.0 ft Drilled to 2968.0 ft Repaired Mud shakers Drilled to 3187.0 ft Held safety meeting Drilled to 3530.0 ft Circulated at 3530.0 ft Pulled out of hole to 1500.0 ft Serviced Top drive R.I.H. to 3530.0 ft Drilled to 3818.0 ft Repaired Mud pumps Drilled to 3910.0 ft Held safety meeting Drilled to 4846.0 ft Circulated at 4846.0 ft Pulled out of hole to 225.0 ft Pulled BHA Serviced Drillfloor / Derrick R.I.H. to 4846.0 ft Drilled to 5075.0 ft Held safety meeting Drilled to 6564.0 ft Serviced Main engine Drilled to 6685.0 ft Circulated at 6685.0 ft Held safety meeting Repaired Flowline Circulated at 6685.0 ft Pulled out of hole to 1100.0 ft R.I.H. to 6685.0 ft Circulated at 6685.0 ft 1 18 June 97 Facility Date/Time 14 Jan 97 15 Jan 97 16 Jan 97 17 Jan 97 18 Jan 97 M Pt K Pad Progress Report Well MPK-33 Page 2 Rig Date 18 June 97 19:00-19:30 19:30-00:00 00:00-02:30 02:30-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-12:00 12:00-15:00 15:00-16:30 16:30-21:00 21:00-00:00 00:00-01:00 01:00-02:30 02:30-06:00 06:00-06:30 06:30-07:30 07:30-10:00 10:00-13:00 13:00-17:00 17:00-18:00 18:00-18:30 18:30-21:00 21:00-23:00 23:00-01:00 01:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-18:30 18:30-19:30 19:30-20:30 20:30-22:30 22:30-00:00 00:00-00:30 00:30-06:00 06:00-06:30 06:30-13:00 13:00-14:00 14:00-14:30 14:30-15:00 15:00-18:00 18:00-18:30 18:30-02:00 02:00-04:00 04:00-06:00 06:00-06:30 06:30-14:00 14:00-15:00 15:00-16:00 16:00-17:00 17:00-18:00 18:00-18:30 Duration 1/2 hr 4-1/2 hr 2-1/2 hr 1 hr 1 hr 1-1/2 hr 1/2 hr 5-1/2 hr 3 hr 1-1/2 hr 4-1/2 hr 3 hr lhr 1-1/2 hr 3-1/2 hr 1/2 hr 1 hr 2-1/2 hr 3 hr 4hr lhr 1/2 hr 2-1/2 hr 2hr 2 hr 3hr 1 hr lhr 1/2 hr 1/2 hr 11-1/2 hr 1 hr lhr 2 hr 1-1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 6-1/2 hr 1 hr 1/2 hr 1/2 hr 3hr 1/2 hr 7-1/2 hr 2 hr 2hr 1/2 hr 7-1/2 hr lhr lhr 1 hr lhr 1/2 hr Activity Held safety meeting Pulled out of hole to 225.0 ft Pulled BHA Rigged up Drillfloor / Derrick Rigged up Casing handling equipment Ran Casing to 1000.0 ft (9-5/8in OD) Held safety meeting Ran Casing to 6666.0 ft (9-5/8in OD) Circulated at 6666.0 ft Mixed and pumped slurry - 330.000 bbl Circulated at 2095.0 ft Mixed and pumped slurry - 500.000 bbl Serviced Fluid system Rigged down Divertor Repaired High pressure lines Held safety meeting Serviced Casing handling equipment Installed Casing spool Rigged up BOP stack Tested BOP stack Installed Wear bushing Held safety meeting Made up BHA no. 3 R.I.H. to 2095.0 ft Drilled installed equipment - DV collar R.I.H. to 6580.0 ft Tested Casing Drilled installed equipment - Landing collar Held safety meeting Performed formation integrity test ~ 12.~'7 e~ Drilled to 8080.0 ft Circulated at 8080.0 ft Pulled out of hole to 6666.0 ft Serviced Top drive Serviced Block line R.I.H. to 8080.0 ft Drilled to 8400.0 ft Held safety meeting Drilled to 9016.0 ft Circulated at 9016.0 ft Pulled out of hole to 8000.0 ft R.I.H. to 9016.0 ft Drilled to 9141.0 ft Held safety meeting Drilled to 9596.0 ft Circulated at 9596.0 ft Drilled to 9700.0 ft Held safety meeting Drilled to 10330.0 ft Circulated at 10330.0 ft Pulled out of hole to 8500.0 ft R.I.H. to 10330.0 ft Drilled to 10395.0 ft Held safety meeting Facility Date/Time 19 Jan 97 20 Jan 97 21 Jan 97 22 Jan 97 23 Jan 97 24 Jan 97 M Pt K Pad Progress Report Well MPK-33 Rig Page Date Duration Activity 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-21:30 21:30-22:30 22:30-00:00 00:00-00:30 00:30-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-11:30 11:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-07:00 07:00-12:00 12:00-13:30 13:30-15:00 15:00-18:00 18:00-18:30 18:30-20:00 20:00-00:00 00:00-02:00 02:00-03:00 03:00-06:00 06:00-06:30 06:30-10:00 10:00-11:30 11:30-12:00 12:00-13:30 13:30-14:00 14:00-18:00 18:00-18:30 18:30-00:00 00:00-00:30 00:30-05:30 05:30-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-10:30 10:30-11:30 11:30-12:30 12:30-13:00 13:00-14:00 14:00-17:00 17:00-19:30 19:30-00:00 00:00-06:00 06:00-10:00 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 3hr lhr 1-1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 1-1/2 hr lhr 2-1/2 hr 6-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr 5 hr 1-1/2 hr 1-1/2 hr 3hr 1/2 hr 1-1/2 hr 4 hr 2 hr lhr 3hr 1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 4 hr 1/2 hr 5-1/2 hr 1/2 hr 5hr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1 hr 1 hr lhr 1/2 hr lhr 3 hr 2-1/2 hr 4-1/2 hr 6hr 4 hr Drilled to 11115.0 ft Held safety meeting Drilled to 11330.0 ft Held safety meeting Drilled to 11410.0 ft Circulated at 11410.0 ft Drilled to 11430.0 ft Circulated at 11410.0 ft Pulled out of hole to 225.0 ft Held safety meeting Downloaded MWD tool Serviced Top drive Made up BHA no. 4 R.I.H. to 11430.0 ft Held safety meeting Drilled to 11543.0 ft Held safety meeting Circulated at 11543.0 ft Pulled out of hole to 225.0 ft Downloaded MWD tool Made up BHA no. 5 R.I.H. to 6666.0 ft Held safety meeting R.I.H. to 11543.0 ft Drilled to 11543.0 ft Pulled out of hole to 8540.0 ft R.I.H. to 11543.0 ft Circulated at 11543.0 ft Held safety meeting Pulled out of hole to 225.0 ft Pulled BHA Removed Wear bushing Rigged up Casing handling equipment Held safety meeting Ran Casing to 820.0 ft (7in OD) Held safety meeting Ran Casing to 6630.0 ft (7in OD) Circulated at 6630.0 ft Ran Casing to 11517.0 ft (7in OD) Circulated at 11517.0 ft Circulated at 11525.0 ft Circulated at 11525.0 ft Rigged down Fluid system Rigged up Cement head Mixed and pumped slurry - 118.000 bbl Displaced slurry - 439.000 bbl Tested Casing Rigged down Cement head Installed Seal assembly Rigged down BOP stack Rigged up Adapter spool Laid out 5in drill pipe from derrick Laid out 5in drill pipe from derrick 3 18 June 97 Milne Point Unit, Alaska To: From: Well Name: Main Category: Sub Category: Operation Date: Rossberg Krieger _.M. Hnkel MPU K-33 Completion E-Line 1/29/97 Date: 11130197 AFE 1347O36 Objective: Run GR/CCL to establish a tie-in log - Perforate Sag River formation - Obtain initial static BHP measurement. Summary: 08:30 12:30 12:45 13:00 13:20 14:00 14:30 15:55 16:40 18:20 18:30 18:45 19:10 20:40 20:55 21:00 21:05 21:20 22:15 22:55 23:40 23:55 RU Schlumberger Wireline Unit # 8345. Pick-up 7" lubricator and pack-off head. Hold pre-job safety meeting. Open well. "0" pressure. (Top master valve 25 1/2 turns to open). Start RIH with GR/CCL on "marked line". Park logging tools at 5950 ft. Crew change-out. Hold second job and safety meeting for new crew. Resume operations and continue in hole. Tag btm. Log up. Used the Sperry-Sun MWD log dated 1/21/97 for lithology. End GR/CCL at 6580 ft. Start OOH. Finish OOH. LD lubricator and logging tools. Re-head to small diameter line for perforating operations. Request radio silence on Pad. Arm gun. Pick-up grease head, lubricator, BOPs, and gun. Open top master and start RIH with 4 1/2" gun. Stop at 11250 ft. Log short joints. Drop back down hole to TD. Log repeat pass. Make a (+) 3 ft correction. Drop back down hole. Log gun into place. Fire gun. Log off. Start OOH. Finish OOH. LD gun. All shots fired. Pick-up CPLT (Serial # A-12) and start . Stop tool at 11260 ft. Log short joints. Make a (+) 2 ft correction. Drop down hole. Pull up hole and park pressure gauge at 11,384 ft MD. 1/30/97 00:15 01:45 01 '46 03:30 04:30 Start to monitor BHP at 3923 psi. Temp at 231.7° F. BHP 4063 psi. (Pressure building at 1 (+) psi/min). Temp 231.6° F. Start out of hole. Finish out of hole close in well. (Wellhead gauge problems - unable to obtain accurate surface reading). RDMO. Tie in log' TD Tag' Schlumberger GR/CCL Dated 1/29/97 11,454 ft ELMD CCL to TS' 4 ft. .......... Interval Measured Depth ......... Top Shot. Btm Shot Gun Diameter Phasing I 11,374 ft. II 11,394 ft II 4.5" II Density Orientation 6 SPF II Random II 60° BP EXPLORATION (ALASKA) INC. Milne Point PRODUCTION ENGINEERING DEPARTMENT TO: Rossberg/ Krieger FROM: Dan Robertson DATE: 2/5/97 RE: MP K-33 SAG DATA FRAC AND FRAC SERVICE CO'S.: Dowell, Peak II Jos SUMMARY Pumped 500 bbl data frac as planned. Results indicated that original frac design with fluid loss coefficient of 0.005 was ok. Pumped frac as per design, except with 61 bbls additional 10 ppg slurry (thought that there was only 6M# excess in silo, but found that there was more). Slowed rate toward end of displacement in attempt to induce screenout. Did not see screenout although surface treating pressure seemed to be increasing toward end of displacement. 134 M# 20/40 proppant placed behind pipe, 3M# left in liner. Well bore left with approx 130' of carbolite above perfs, 83 bbls diesel to 2167 MD, and seawater below this to perfs. Estimated top of carbolite at 11240 MD. Note reservoir pressure estimated at 4510 psi (9.5 ppg EMW) based on pre job hydrostatics with 585 psi whp. INJECTIVITY TEST Design Rate, Bbls Max Rate, Final STP, ISIP, NWB Treat grad, BPM Pumped bpm psi PSI friction, psi psi/ft 3 0 5 0 3 0 2730 2040 n/a 0.66 DATA FRAC Bbls Bbls XL Time XL gel Final STP, ISIP, psi NWB Treat grad, Pumped gel on perfs psi friction, psi/ft through psi Perfs 500 490 16.3 31 25 2550 400 0.72 Pclosure Pclosure Pnet P* Closure fluid loss fluid Surface Bottomhol psi psi/rad time, min coefficient efficiency, psi e psi min^-0.5' % 2050 61 22 51 0 1 077 4.8 0.0049 I 9 'i88 -188 191Sd 91SdI laid8 SIN=II~llAIO~3 IAII3~ =l~9~.lSI dH/~A dNN~I :1.1.~1 =l~l.1 .~. ^a~ns 9N~a~n~· PUMPING BPM IPS~G IPS~GI BBL BBL SUMMARY COMMENTS FRA C Sand Lead prop Tail prop Design total Tresaver pumped, behind behind behind Liner rubber left Job was M# pipe, M# pipe, M# pipe, M# Sand, M# in hole? /size /size flush I 37 I 34 I 17 3 NO 20/40 n/a Ft of Estimated Final ISlP, psi ISlP Incr pad TSO, TSO, sand in sand top STP, over fraction design, Nolte P i pe psi datafrac % min P lot 130 11240 3200 3060 500 42 21 ? DATE/TIME OPERATIONS SUMMARY I 2/5/97 DATA FRAC MIRU fmc, vac, pump. AMBIENT=I-7), WIND=10 MPH. SIWHP= 585 psi, OAP= 270 psi Reservoir pressure estimated at 4510 psi based on whp with 2100' of diesel and remainder seawater in wellbore. Pre job operational and safety meeting. Set treesaver. PT lines at 1500, 7600 psi. Test pump trips. Start data frac. 2~5~97 FRAC PUMP FRAC AS PER ORIGINAL TSO. SECURE WELL. RDMO frac, vac, pump. PUMPING SUMMARY TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL 2/5/97 DATA FRAC 1215 0/30 330 2800 0 0 Est rate w/seawater 1218 30/0 400 2730 100 100 sd for ISIP=2040 psi, 0.66 psi/ft, seawater and approx 1000' tvd of diesel in hole at shutdown. 1236 0/30 400 1800 0 100 Stg 40# XL gel pad 1239 29.9 465 2760 100 200 1242 29.9 550 3100 200 300 1246 29.9 608 3377 300 400 1250 29.9 675 3700 436 536 xlink gel at perfs. 1253 29.8 692 3980 500/0 600 Stage flush w/seawater 1257 29.9 738 3880 100 700 1300 30.0 750 3600 200 800 · 1303 29.9 750 3440 300 900 PUMPING SUMMARY '~-'~ TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL 1307 30.4 750 3125 426/0 1026 SD pumps. ISIP=2550 psi, FG= 0.72 psi/ft with slick seawater in hole. NWBF= 400 psi. MonitorWHP. FRAC 1405 0/30 550 1500 0 0 Stage pad 1408 29.9 520 2790 100 100 1411 29.9 580 2970 200 200 1414 29.9 600 3120 300 300 1419 29.9 660 3440 465/0 465 Stage 1 ppg 20/40 CL. pad at perfs at 426 bbls 1427 29.9 680 3790 171/0 636 Stage 2 ppg 38/0 674 3 ppg. 1428 30.0 685 3770 46/0 721 4 ppg 53/O 774 5 ppg 1432 30.4 640 3514 57/0 831 6 ppg 1435 29.9 600 3250 59/0 890 7 ppg, I ppg at perfs at 901 cum 62/0 952 8 ppg 1439 29.9 590 3050 62/0 1 014 9 ppg 1441 29.9 556 2860 62/0 1076 10 ppg. 2 ppg at perfs at 1072 cum 30.6 530 2560 178/0 1254 Stage flush. 3 ppg at perfs at1110 cum, 4ppg at perfs at 1156 cum bleed in 83 bbls diesel with flush lO0 5 ppg on perfs 1451 30.4 570 2570 1 O0 1354 6 ppg on perfs 7 ppg on perfs 1453 29.8 595 2650 187 1441 8 ppg on perfs 1455 29.9 600 2670 238 1491 9 ppg on perfs 1458 30.1 626 2900 1570 10 ppg on perfs 1500 30 3100 reduce rate. ,1501 10 611 3189 421/0 1675 Sd pumps. MonitorWHP. ISIP=3060 psi. Page 5 FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 1026 FRAC: 1675 Diesel 80 Bbls Bbls BBLS 2781 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME GEL QUALITY CONTROL CHECK SEA H20 SEA H20 40# GEL 40# GEL PIPE XL XL pH TEMP pH VISCOSITY TIME TIME pH DF/FRAC 7.5 98 F 7.41 34 14.5 2'15 8.8 FLUID ADDITIVES DOWELL YF140D FLUID SYSTEM with 40 PPT adomite regain in data frac and pad. Sieve analysis: 19.7% of prop would not pass through 20 mesh screen, 79.3% would not pass through 30 mesh screen, 0.3% fines, 0.5% larger than 20 mesh. SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPK-33 Rig Name: N-4ES AFE: 347036 Accept Date: 02/07/97 Spud Date: - Release Date: 02/11/97 Feb 8 1997 Scope derrick down, lower derrick. MIRU. Rig accepted 02/0797 @ 1400 hrs. ND tree, NU BOP, pull BPV. Test BOP per SSD requirements. State waived by J. Spalding. Test 250# to 5000#. Load pits with brine, Icad pipe shed with 2-7/8" tubing. Remove protectors. MU RBP retrieve tool, RIH 2-7/8" tubing, drift., SLM, 2100'. Circ out diesel protect to tiger tank, displ with brine @ 2100'. Feb 9 1997 RIH 2-7/8" workstring to 10794'. Rev circ, displ well with brine, spot Xanvis pill on top of RBP. Engage RBP with circ @ 10862', equalize RBP, monitor well, release RBP. Relax seals, RIH to 10887'. Circ pill around to bottoms up, monitor well static. TOH with RBP, wet string, LD RBP & retrieve tool. MU mule shoe RIH to 6600'. Slip, cut drill line. Cont RIH with mule shoe to clean out sand. Feb 10 1997 Rev circ sand @ 11483', monitor well. Rev clean @ 11483', spot LCM pill across perfs (Xanvis + liquid casing). TOH to 11171 ', monitor well fluid loss. Displ well with clean filter brine. 112 NTU returns. Clean pits w/o brine. TOH with mule shoe. MU casing scraper, RIH to 50' above perfs @ 11324'. Rev circ, perf casing wash, chase caustic pill follow with clean filter brine. Feb 11 1997 Circ casing wash around, filter brine with DE unit, return fluid 31 NTU, monitor well static. TOH with tubing & 7" casing scraper, LD 6 jts & scraper assy. RU to run ESP. MU service test ESP assy, test line (confirm shaft fit). RIH with ESP assy. MU cable splice @ 8500'. Cont RIH, MU hanger & LD JT. MU splice @ hanger. LD tubing, RILDS, LD landing jt, install 2 way check valve. Feb 12 1997 ND BOP, NU compl tree. Test adapter & tree, test surface lines. Test ESP pent, ok. Freeze protect well 68 bbls annul, 12 bbls tubing. RD cellar, secure well. Rig released 02/11/97 @ 1200 hrs. Page ,RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT / MPK-33 500292272900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/26/97 DATE OF SURVEY: 012297 MWD SURVEY JOB NUMBER: AK-MM-70005 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -61.10 208.20 208.20 147.10 293.93 293.92 232.82 381.81 381.79 320.69 471.87 471.84 410.74 0 0 N .00 E .00 .00N .00E 0 26 S 58.52 E .21 .42S .68E 0 40 S 81.86 E .38 .66S 1.47E 1 4 S 67.46 E .51 1.05S 2.74E 1 7 S 70.83 E .09 1.66S 4.35E .00 .80 1.61 2.92 4.63 562.99 562.93 501.83 653.25 653.13 592.03 743.38 743.16 682.06 831.70 831.32 770.22 919.12 918.44 857.34 1 43 S 86.42 E .79 2.04S 6.56E 2 16 S 81.27 E .63 2.40S 9.69E 3 8 S 84.38 E .98 2.91S 13.91E 3 45 S 85.44 E .71 3.38S 19.20E 5 32 S 85.31 E 2.04 3.95S 26.27E 6 .77 9.72 13.72 18.65 25.21 1010.56 1009.36 948.26 1105.80 1103.99 1042.89 1198.47 1196.08 1134.98 1291.01 1287.83 1226.73 1386.08 1381.76 1320.66 6 39 S 83.22 E 1.25 4.94S 35.93E 6 17 S 78.52 E .68 6.63S 46.53E 6 30 S 59.20 E 2.32 10.32S 56.01E 8 37 S 36.58 E 3.91 18.58S 64.64E 9 6 S 30.66 E 1.09 30.77S 72.73E 34.27 44.48 54.61 66.05 78.78 1479.59 1474.06 1412.96 1574.84 1567.94 1506.84 1668.80 1660.00 1598.90 1762.64 1750.97 1689.87 1858.75 1843.63 1782.53 9 22 S 32.61 E .44 43.56S 80.61E 10 1 S 36.86 E 1.02 56.73S 89.77E 13 0 S 42.04 E 3.35 71.14S 101.76E 15 24 S 38.35 E 2.73 88.76S 116.57E 15 21 S 36.37 E .55 109.03S 132.04E 91.60 105.73 122.94 144.13 167.10 1950.33 1931.67 1870.57 2045.50 2022.25 1961.15 2139.32 2110.38 2049.28 2235.23 2198.90 2137.80 2324.89 2279.94 2218.84 16 36 S 38.64 E 1.52 129.01S 147.40E 19 6 S 40.94 E 2.74 151.40S 166.10E 20 58 S 41.72 E 2.00 175.53S 187.34E 24 15 S 44.05 E 3.55 202.51S 212.47E 26 21 S 45.96 E 2.51 229.59S 239.58E 189.85 216.66 246.52 281.15 317.59 2422.30 2366.14 2305.04 2516.46 2447.31 2386.21 2611.97 2527.19 2466.09 2702.67 2600.81 2539.71 2794.00 2673.06 2611.96 29 8 S 45.74 E 2.86 261.18S 272.12E 31 45 S 47.38 E 2.91 293.96S 306.78E 34 42 S 47.88 E 3.11 329.22S 345.45E 36 45 S 49.05 E 2.37 364.33S 385.10E 38 39 S 49.12 E 2.09 400.90S 427.30E 360.90 406.65 457.09 508.34 562.53 2888.54 2745.37 2684.27 2984.67 2816.16 2755.06 3079.01 2883.12 2822.02 3172.95 2947.04 2885.94 3264.93 3007.37 2946.27 41 32 S 46.70 E 3.47 441.74S 472.46E 43 34 S 45.70 E 2.23 486.75S 519.37E 45 57 S 44.39 E 2.70 533.69S 566.36E 48 16 S 44.35 E 2.47 582.88S 614.48E 49 45 S 44.11 E 1.63 632.63S 662.91E 621.29 683.50 746.65 811.83 877.54 ORIGINAL Alas~ Oit & G~s uo,qs. ~,~. - PAGE 2 RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING MILNE PT / MPK-33 500292272900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/26/97 DATE OF SURVEY: 012297 MWD SURVEY JOB NUMBER: AK-MM-70005 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3359.40 3066.37 3005.27 52 55 3451.56 3121.37 3060.27 53 46 3548.30 3178.21 3117.11 54 15 3642.87 3232.78 3171.68 55 15 3734.87 3284.29 3223.19 56 38 S 44.39 E 3.36 685.46S 714.38E S 45.10 E 1.11 737.97S 766.44E S 43.41 E 1.49 794.04S 821.06E S 43.11 E 1.10 850.28S 873.98E S 43.95 E 1.68 905.54S 926.48E 947.36 1017.55 1091.64 1164.30 1236.13 3832.25 3337.20 3276.10 3925.25 3386.83 3325.73 4018.25 3436.88 3375.78 4111.82 3488.06 3426.96 4204.55 3538.26 3477.16 57 32 57 57 56 56 56 44 57 42 S 46.49 E 2.38 963.10S 984.50E S 48.39 E 1.78 1016.29S 1042.42E S 47.61 E 1.30 1068.73S 1100.67E S 46.55 E .97 1122.07S 1158.04E S 46.34 E 1.05 1175.79S 1214.53E 1313.93 1389.66 1465.35 1540.65 1615.35 4300.10 3589.70 3528.60 57 4391.99 3638.87 3577.77 58 4485.48 3688.53 3627.43 57 4577.82 3738.48 3677.38 56 4672.24 3789.88 3728.78 57 9 7 42 48 13 S 45.46 E .96 1231.82S 1272.36E S 45.61 E 1.06 1286.20S 1327.76E S 45.76 E .48 1341.53S 1384.43E S 45.65 E .97 1395.77S 1440.02E S 44.05 E 1.49 1451.91S 1495.87E 1692.28 1766.29 1841.89 1916.01 1991.23 4767.15 3840.45 3779.35 4860.69 3889.40 3828.30 4953.72 3938.18 3877.08 5049.09 3989.39 3928.29 5141.85 4041.05 3979.95 58 22 58 30 58 14 56 48 55 29 S 43.65 E 1.27 1509.83S 1551.50E S 43.10 E .52 1567.77S 1606.24E S 44.30 E 1.14 1625.03S 1660.97E S 44.21 E 1.50 1682.66S 1717.11E S 44.30 E 1.43 1737.83S 1770.87E 2067.06 2142.11 2216.83 2292.98 2365.90 5235.96 4094.47 4033.37 55 20 5328.08 4147.01 4085.91 55 5 5423.15 4201.34 4140.24 55 11 5518.28 4256.09 4194.99 54 31 5613.39 4311.74 4250.64 53 50 S 43.84 E .43 1793.50S 1824.76E S 43.94 E .28 1848.03S 1877.22E S 43.98 E .10 1904.19S 1931.37E S 43.96 E .69 1960.17S 1985.38E S 43.57 E .79 2015.88S 2038.73E 2439.16 2510.63 2584.34 2657.85 2730.65 5706.88 4366.59 4305.49 54 18 5800.94 4421.09 4359.99 54 52 5892.85 4473.95 4412.85 54 54 5987.36 4529.39 4468.29 53 14 6082.29 4586.66 4525.56 52 32 S 42.42 E 1.11 2071.25S 2090.36E S 42.49 E .60 2127.81S 2142.10E S 42.33 E .15 2183.32S 2192.81E S 42.51 E 1.77 2239.82S 2244.43E S 42.06 E .82 2295.82S 2295.37E 2801.75 2873.50 2943.86 3015.46 3086.24 6175.96 4643.87 4582.77 52 9 6268.39 4700.76 4639.66 51 52 6361.16 4758.29 4697.19 51 28 6457.47 4818.05 4756.95 51 48 6552.15 4876.60 4815.50 51 47 S 42.44 E .53 2350.73S 2345.24E S 42.34 E .33 2404.53S 2394.35E S 42.34 E .42 2458.33S 2443.37E S 40.77 E 1.32 2514.84S 2493.46E S 40.96 E .16 2571.11S 2542.14E 3155.57 3223.73 3291.79 3362.05 3430.93 S PAGE 3 RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING MILNE PT / MPK-33 500292272900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/26/97 DATE OF SURVEY: 012297 MWD SURVEY JOB NUMBER: AK-MM-70005 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6594.06 4902.61 4841.51 6740.76 4993.90 4932.80 6842.38 5056.90 4995.80 6936.89 5115.40 5054.29 7029.81 5172.97 5111.87 51 29 51 32 51 50 51 40 51 44 S 42.73 E 3.39 2595.59S 2564.06E S 41.23 E .80 2680.94S 2640.86E S 41.24 E .29 2740.91S 2693.42E S 40.97 E .28 2796.84S 2742.23E S 41.53 E .48 2851.67S 2790.31E 3461.56 3568.69 3642.71 3711.55 3779.26 7123.99 5231.00 5169.90 7218.31 5290.65 5229.55 7311.48 5353.38 5292.28 7406.12 5420.34 5359.24 7499.11 5487.07 5425.97 52 11 49 21 45 59 43 57 44 19 S 41.85 E .55 2907.06S 2839.65E S 45.57 E 4.28 2959.89S 2890.08E S 48.60 E 4.34 3006.81S 2940.48E S 50.92 E 2.77 3050.03S 2991.51E S 51.22 E .47 3090.72S 3041.89E 3848.33 3917.22 3983.41 4048.48 4111.82 7595.82 5556.28 5495.18 7689.70 5624.67 5563.57 7784.72 5696.48 5635.38 7879.16 5770.72 5709.62 7973.83 5847.72 5786.62 44 16 42 13 39 34 36 45 34 22 S 51.16 E .06 3133.06S 3094.53E S 54.02 E 3.03 3172.15S 3145.59E S 55.92 E 3.07 3207.88S 3196.51E S 55.57 E 2.99 3240.72S 3244.74E S 57.04 E 2.68 3271.28S 3290.53E 4177.92 4241.15 4302.73 4360.61 4415.27 8067.53 5926.01 5864.91 8160.24 6005.49 5944.39 8254.69 6088.47 6027.37 8349.70 6173.71 6112.61 8444.31 6260.10 6199.00 32 14 29 43 27 20 25 6 22 57 S 58.64 E 2.46 3298.67S 3334.06E S 56.57 E 2.94 3324.21S 3374.37E S 51.61 E 3.56 3350.59S 3410.93E S 47.71 E 2.97 3377.71S 3442.94E S 46.82 E 2.29 3403.83S 3471.24E 4466.49 4514.00 4558.54 4599.36 4636.42 8537.74 6346.97 6285.87 8630.11 6434.27 6373.17 8724.22 6524.48 6463.38 8816.52 6613.53 6552.43 8908.79 6703.06 6641.96 20 13 17 51 15 12 15 16 12 41 S 46.83 E 2.93 3427.36S 3496.31E S 47.71 E 2.58 3447.80S 3518.43E S 47.30 E 2.81 3465.88S 3538.17E S 47.29 E .07 3482.34S 3556.01E S 46.02 E 2.82 3497.64S 3572.24E 4669.43 4698.41 4724.20 4747.55 4768.96 9006.08 6798.52 6737.42 9096.80 6888.23 6827.13 9196.10 6986.65 6925.55 9289.25 7078.90 7017.80 9382.38 7171.03 7109.93 9 30 7 36 7 39 8 16 8 31 S 41.01 E 3.43 3511.13S 3585.21E S 28.39 E 2.92 3522.06S 3592.98E S 30.08 E .23 3533.57S 3599.42E S 37.40 E 1.28 3544.27S 3606.61E S 37.43 E .26 3555.08S 3614.87E 4786.63 4798.51 4809.46 4820.72 4832.98 9476.13 7263.76 7202.66 9570.47 7357.06 7295.96 9664.02 7449.59 7388.49 9759.23 7543.73 7482.63 9852.03 7635.45 7574.35 27 30 29 40 50 S 38.76 E .22 3565.97S 3623.41E S 39.13 E .07 3576.79S 3632.16E S 40.60 E .23 3587.40S 3641.01E S 41.45 E .23 3598.11S 3650.34E S 41.11 E .19 3608.73S 3659.66E 4845.53 4858.22 4870.92 4884.09 4897.20 S RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING MILNE PT / MPK-33 500292272900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/26/97 DATE OF SURVEY: 012297 MWD SURVEY JOB NUMBER: AK-MM-70005 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9946.44 7728.74 7667.64 8 50 S 41.78 E .11 3619.60S 3669.26E 10039.52 7820.71 7759.61 8 51 S 41.98 E .04 3630.26S 3678.82E 10134.37 7914.47 7853.37 8 34 S 43.16 E .36 3640.85S 3688.54E 10225.59 8004.70 7943.60 8 16 S 44.79 E .41 3650.47S 3697.82E 10320.20 8098.34 8037.24 8 10 S 47.05 E .36 3659.89S 3707.54E 4910.69 4924.04 4937.50 4950.13 4963.07 10412.56 8189.76 8128.66 8 9 S 47.86 E .13 3668.76S 3717.21E 10505.88 8282.11 8221.01 8 20 S 48.38 E .21 3677.70S 3727.18E 10600.26 8375.50 8314.40 8 18 S 48.16 E .05 3686.80S 3737.38E 10692.86 8467.15 8406.05 8 4 S 49.55 E .33 3695.48S 3747.32E 10788.27 8561.63 8500.54 7 55 S 49.94 E .18 3704.06S 3757.45E 4975.71 4988.65 5001.86 5014.65 5027.57 10882.21 8654.68 8593.58 7 56 S 50.11 E .04 3712.39S 3767.38E 10978.31 8749.88 8688.78 7 43 S 49.38 E .25 3720.85S 3777.38E 11071.51 8842.25 8781.15 7 34 S 48.59 E .20 3728.99S 3786.73E 11166.64 8936.58 8875.48 7 18 S 47.48 E .31 3737.22S 3795.89E 11259.34 9028.55 8967.45 7 6 S 45.85 E .31 3745.20S 3804.36E 5040.20 5052.94 5064.96 5076.86 5088.02 11352.65 9121.10 9060.00 7 28 S 42.71 E .58 3753.68S 3812.61E 11434.14 9201.91 9140.81 7 22 S 42.57 E .13 3761.42S 3819.74E 11543.00 9309.87 9248.77 7 22 S 42.57 E .02 3771.71S 3829.19E 5099.22 5109.09 5122.17 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5374.80 FEET AT SOUTH 45 DEG. 25 MIN. EAST AT MD = 11543 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 116.93 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 10,543.00' MD 3 0 !997 Alaska 0il & Gas Cons, uoroPn,-~-" Anchoraa~e PAGE 5 RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING MILNE PT / MPK-33 500292272900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/26/97 DATE OF SURVEY' 012297 JOB NUMBER: AK-MM-70005 KELLY BUSHING ELEV. = 61.10 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -61.10 .00 N .00 E 1000.00 998.87 937.77 4.79 S 34.71 E 2000.00 1979.10 1918.00 140.41 S 156.74 E 3000.00 2827.26 2766.16 494.13 S 526.94 E 4000.00 3426.92 3365.82 1058.42 S 1089.38 E .00 1.13 1.13 20.90 19.76 172.74 151.84 573.08 400.34 5000.00 3962.54 3901.44 1653.20 S 1688.45 E 6000.00 4536.96 4475.86 2247.28 S 2251.27 E 7000.00 5154.51 5093.41 2834.15 S 2774.79 E 8000.00 5869.32 5808.22 3279.32 S 3302.93 E 9000.00 6792.52 6731.42 3510.36 S 3584.54 E 1037.46 464.38 1463.04 425.59 1845.49 382.45 2130.68 285.20 2207.48 76.79 10000.00 7781.66 7720.56 3625.74 S 3674.75 E 11000.00 8771.37 8710.27 3722.75 S 3779.59 E 11543.00 9309.87 9248.77 3771.71 S 3829.19 E 2218.34 10.86 2228.63 10.29 2233.13 4.50 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. 2RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT / MPK-33 500292272900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/26/97 DATE OF SURVEY: 012297 JOB NUMBER: AK-MM-70005 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 61.10 61.10 161.10 161.10 261.11 261.10 361.11 361.10 -61.1 .0 100.0 200.0 300.0 0 .00 N .00 0 .00 N .00 0 .23 S .37 0 .61 S 1.08 0 .90 S 2.38 E .00 E .00 .00 E .00 .00 E .01 .00 E .01 .01 461.13 461.10 561.16 561.10 661.23 661.10 761.35 761.10 861.55 861.10 400.0 500.0 600.0 700.0 800.0 1.59 S 4.15 2.04 S 6.51 2.44 S 10.00 3.01 S 14.89 3.53 S 21.17 E .03 .02 E .06 .03 E .13 .06 E .25 .12 E .45 .20 961.99 961.10 1062.65 1061.10 1163.26 1161.10 1264.00 1261.10 1365.15 1361.10 900.0 1000.0 1100.0 1200.0 1300.0 4 5 8 15 27 .30 S 30.42 .68 S 41.90 .28 S 52.59 .59 S 62.20 .92 S 71.04 E .89 .44 E 1.55 .67 E 2.16 .61 E 2.90 .74 E 4.05 1.15 1466.46 1461.10 1567.89 1561.10 1669.93 1661.10 1773.15 1761.10 1876.86 1861.10 1400.0 1500.0 1600.0 1700.0 1800.0 41 55 71 90 112 .75 S 79.46 .77 S 89.04 .35 S 101.95 .95 S 118.31 .89 S 134.89 E 5.36 1.30 E 6.79 1.43 E 8.83 2.04 E 12.05 3.22 E 15.76 3.71 1981 2086 2194 2303 2416 .11 1961.10 .65 2061.10 00 2161.10 .86 2261.10 54 2361.10 1900.0 2000.0 2100.0 2200.0 2300.0 136 161 190 223 259 .00 S 153.08 .63 S 174.99 .60 S 201.13 .10 S 232.87 .24 S 270.13 E 20.01 4.24 E 25.55 5.54 E 32.90 7.36 E 42.76 9.86 E 55.44 12.68 2532 2653 2778 2909 3047 74 2461.10 .26 2561.10 68 2661.10 .56 2761.10 34 2861.10 2400.0 2500.0 2600.0 2700.0 2800.0 299 345 394 451 517 .81 S 313.15 .01 S 362.94 .64 S 420.07 .31 S 482.61 .42 S 550.44 E 71.63 16.19 E 92.16 20.52 E 117.58 25.43 E 148.46 30.88 E 186.24 37.77 3194 07 3350.73 3519.01 3692.81 3876.79 2961.1 3061.1 3161.1 3261.1 3361.1 2900.0 3000.0 3100.0 3200.0 3300.0 594.15 680.54 776.77 880.25 988.96 S 625.50 S 709.57 S 804.72 S 902.16 S 1011.78 E 232.97 46.73 E 289.63 56.66 E 357.91 68.28 E 431.71 73.80 E 515.69 83.98 PAGE 7 RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING MILNE PT / MPK-33 500292272900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/26/97 DATE OF SURVEY' 012297 JOB NUMBER: AK-MM-70005 KELLY BUSHING ELEV. = 61.10 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4062.65 3461.10 3400.00 4247.25 3561.10 3500.00 4434.08 3661.10 3600.00 4619.15 3761.10 3700.00 4806.54 3861.10 3800.00 1093.84 S 1128.13 E 1200.73 S 1240.61 E 1311.20 S 1353.30 E 1419.94 S 1464.75 E 1534.11 S 1574.64 E 601.55 85.85 686.15 84.61 772.98 86.83 858.05 85.07 945.44 87.39 4997.26 3961.10 3900.00 5177.23 4061.10 4000.00 5352.71 4161.10 4100.00 5526.91 4261.10 4200.00 5697.48 4361.10 4300.00 1651.53 S 1686.82 E 1758.70 S 1791.23 E 1862.58 S 1891.24 E 1965.23 S 1990.26 E 2065.61 S 2085.20 E 1036.16 90.72 1116.13 79.98 1191.61 75.48 1265.81 74.20 1336.38 70.57 5870.50 4461.10 4400.00 6040.25 4561.10 4500.00 6204.04 4661.10 4600.00 6365.68 4761.10 4700.00 6527.09 4861.10 4800.00 2169.80 S 2180.50 E 2271.05 S 2273.01 E 2367.09 S 2360.21 E 2460.94 S 2445.75 E 2556.24 S 2529.24 E 1409.40 73.02 1479.15 69.75 1542.94 63.79 1604.58 61.63 1665.99 61.41 6688.02 4961.10 4900.00 6849.18 5061.10 5000.00 7010.64 5161.10 5100.00 7172.27 5261.10 5200.00 7322.55 5361.10 5300.00 2649 88 S 2744.93 S 2840 40 S 2934.75 S 3012 05 S 2613.65 E 1726.92 60.93 2696.95 E 1788.08 61.16 2780.33 E 1849.54 61.46 2865.30 E 1911.17 61.63 2946.45 E 1961.45 50.29 7462.80 5461.10 5400.00 7602.53 5561.10 5500.00 7738.37 5661.10 5600.00 7867.10 5761.10 5700.00 7990.04 5861.10 5800.00 3074 83 S 3135.98 S 3190 90 S 3236.62 S 3276 26 S 3022.11 E 2001.70 40.25 3098.18 E 2041.43 39.73 3171.86 E 2077.27 35.84 3238.75 E 2106.00 28.73 3298.21 E 2128.94 22.94 8108.75 5961.10 5900.00 8223.76 6061.10 6000.00 8335.75 6161.10 6100.00 8445.39 6261.10 6200.00 8552.80 6361.10 6300.00 3310 08 S 3341.83 S 3373.72 S 3404.11 S 3430.92 S 3352.44 E 3399.50 E 3438.50 E 3471.54 E 3500.11 E 2147.65 18.70 2162.66 15.02 2174.65 11.99 2184.29 9.63 2191.70 7.41 8658.23 6461.10 6400.00 8762.17 6561.10 6500.00 8865.67 6661.10 6600.00 8968.06 6761.10 6700.00 9069.40 6861.10 6800.00 3453.48 S 3472.64 S 3490.78 S 3506.17 S 3518.83 S 3524.66 E 3545.49 E 3565.05 E 3580.70 E 3591.04 E 2197.13 5.43 2201.07 3.93 2204.57 3.50 2206.96 2.40 2208.30 1.34 PAGE 8 RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING MILNE PT / MPK-33 500292272900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/26/97 DATE OF SURVEY' 012297 JOB NUMBER: AK-MM-70005 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 9170.32 6961.10 6900.00 3530.60 S 3597.70 E 2209.22 .91 9271.26 7061.10 7000.00 3542.21 S 3605.04 E 2210.16 .94 9372.33 7161.10 7100.00 3553.90 S 3613.97 E 2211.23 1.08 9473.44 7261.10 7200.00 3565.66 S 3623.17 E 2212.34 1.11 9574.55 7361.10 7300.00 3577.26 S 3632.54 E 2213.45 1.10 9675.66 7461.10 7400.00 3588.70 S 3642.13 E 2214.56 1.11 9776.80 7561.10 7500.00 3600.10 S 3652.09 E 2215.70 1.14 9877.99 7661.10 7600.00 3611.73 S 3662.28 E 2216.89 1.19 9979.19 7761.10 7700.00 3623.35 S 3672.61 E 2218.09 1.20 10080.40 7861.10 7800.00 3634.94 S 3683.03 E 2219.30 1.21 10181.53 7961.10 7900.00 3645.97 S 3693.35 E 2220.43 1.13 10282.58 8061.10 8000.00 3656.24 S 3703.62 E 2221.48 1.05 10383.61 8161.10 8100.00 3666.01 S 3714.17 E 2222.51 1.03 10484.64 8261.10 8200.00 3675.66 S 3724.88 E 2223.54 1.03 10585.71 8361.10 8300.00 3685.40 S 3735.81 E 2224.61 1.07 10686.75 8461.10 8400.00 3694.93 S 3746.66 E 2225.65 1.04 10787.73 8561.10 8500.00 3704.02 S 3757.40 E 2226.63 .98 10888.70 8661.10 8600.00 3712.97 S 3768.07 E 2227.60 .97 10989.63 8761.10 8700.00 3721.84 S 3778.53 E 2228.53 .94 11090.52 8861.10 8800.00 3730.64 S 3788.61 E 2229.42 .89 11191.36 8961.10 8900.00 3739.35 S 3798.21 E 2230.26 .84 11292.14 9061.10 9000.00 3748.03 S 3807.27 E 2231.04 .78 11392.99 9161.10 9100.00 3757.53 S 3816.16 E 2231.89 .84 11493.82 9261.10 9200.00 3767.06 S 3824.92 E 2232.72 .83 11543.00 9309.87 9248.77 3771.71 S 3829.19 E 2233.13 .41 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS S~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION (ALASKA) MILNE POINT / MPK-33 500292272900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 4/97 DATE OF SURVEY: 012197 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70019 KELLY BUSHING ELEV. = 61.10 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DGMN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6594.06 4902.76 4841.66 51 29 6770.95 5012.67 4951.57 51 40 6864.88 5070.60 5009.50 52 9 6959.48 5128.85 5067.75 51 49 7053.73 5187.08 5125.98 51 50 S 42.73 E .00 2595.67S 2564.15E S 41.86 E .40 2698.19S 2657.42E S 41.16 E .78 2753.56S 2706.42E S 40.82 E .45 2809.82S 2755.31E S 41.37 E .46 2865.67S 2804.02E 3461.68 3591.26 3660.02 3729.10 3797.82 7147.35 5245.03 5183.93 51 40 7241.06 5305.36 5244.26 48 10 7335.26 5370.07 5308.97 45 2 7428.65 5436.61 5375.51 44 3 7522.45 5503.72 5442.62 44 34 S 41.82 E .43 2920.66S 2852.83E S 46.30 E 5.22 2972.21S 2902.62E S 49.07 E 3.95 3018.31S 2953.20E S 51.66 E 2.22 3060.10S 3003.64E S 52.52 E .84 3100.36S 3055.34E 3866.25 3933.98 3999.95 4063.85 4128.18 7618.26 5572.28 5511.18 44 3 7712.16 5641.31 5580.21 41 17 7807.26 5714.12 5653.02 38 46 7901.46 5789.09 5727.99 35 44 7996.91 5867.50 5806.40 33 45 S 52.54 E .55 3141.08S 3108.46E S 54.54 E 3.27 3178.92S 3159.63E S 56.30 E 2.91 3213.65S 3209.97E S 56.57 E 3.21 3245.18S 3257.48E S 56.87 E 2.09 3275.04S 3302.96E 4193.98 4256.74 4317.35 4373.99 4428.06 8089.84 5945.86 5884.76 31 13 8182.46 6025.95 5964.85 29 2 8276.86 6109.42 6048.32 26 39 8371.80 6195.13 6134.03 24 17 8466.40 6282.01 6220.91 22 17 S 57.30 E 2.73 3302.17S 3344.86E S 55.04 E 2.67 3328.02S 3383.48E S 50.67 E 3.32 3354.57S 3418.65E S 47.54 E 2.87 3381.26S 3449.54E S 47.46 E 2.12 3406.53S 3477.11E 4477.70 4523.84 4567.22 4606.85 4642.87 8560.16 6369.57 6308.47 19 34 8651.78 6456.51 6395.41 17 8 8746.44 6547.37 6486.27 15 24 8839.39 6637.20 6576.10 14 18 8933.71 6729.11 6668.01 11 36 S 46.34 E 2.92 3429.40S 3501.57E S 46.99 E 2.67 3449.20S 3522.54E S 47.60 E 1.83 3467.19S 3542.03E S 47.54 E 1.18 3483.28S 3559.63E S 45.42 E 2.92 3497.81S 3574.99E 4675..04 4702.71 4728.23 4751.21 4771.49 9028.80 6822.70 6761.60 9123.83 6916.75 6855.65 9219.22 7011.26 6950.16 9312.15 7103.25 7042.15 9405.69 7195.74 7134.64 42 S 38.04 E 3.33 3510.20S 3586.25E 43 S 30.21 E 1.56 3521.39S 3593.90E 52 S 33.37 E .47 3532.39S 3600.72E 29 S 38.40 E 1.02 3543.08S 3608.48E 40 S 39.30 E .24 3553.95S 3617.24E 4787.13 4799.02 4810.08 4821.84 4834.57 9498.60 7287.60 7226.50 9593.53 7381.47 7320.37 9687.53 7474.41 7413.31 9781.97 7567.76 7506.66 9872.54 7657.25 7596.15 8 33 8 34 8 38 8 49 8 5O S 40.21 E .20 3564.65S 3626.14E S 40.59 E .06 3575.41S 3635.30E S 41.48 E .15 3586.02S 3644.53E S 42.00 E .22 3596.72S 3654.08E S 41.79 E .04 3607.08S 3663.37E 4847.35 4860.40 4873.44 4886.79 4899.77 S' PAGE 2 ~RY-SUN DRILLING SERVICES - ANCHORAGE ALASKA BP EXPLORATION (ALASKA) MILNE POINT / MPK-33 500292272900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 4/97 DATE OF SURVEY: 012197 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70019 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 9998.04 7781.26 7720.16 8 52 S 42.27 E .06 3621.43S 3676.30E 4917.80 10090.05 7872.17 7811.07 8 49 S 42.88 E .11 3631.85S 3685.88E 4931.06 10184.60 7965.64 7904.54 8 29 S 44.57 E .44 3642.15S 3695.72E 4944.49 10277.68 8057.73 7996.63 8 12 S 46.95 E .49 3651.58S 3705.40E 4957.40 10369.79 8148.89 8087.79 8 15 S 48.39 E .23 3660.47S 3715.16E 4970.12 10408.00 8186.70 8125.60 8 19 S 48.78 E .20 3664.11S 3719.29E 4975.46 10464.90 8243.00 8181.90 8 19 S 48.54 E .06 3669.55S 3725.48E 4983.43 10558.48 8335.59 8274.49 8 21 S 48.08 E .08 3678.59S 3735.62E 4996.57 10651.96 8428.09 8366.99 8 16 S 48.99 E .17 3687.54S 3745.75E 5009.66 10744.92 8520.11 8459.01 8 4 S 50.63 E .32 3696.07S 3755.84E 5022.52 10839.94 8614.19 8553.09 8 2 S 50.75 E .05 3704.51S 3766.15E 5035.53 10934.32 8707.66 8646.56 7 52 S 49.86 E .22 3712.85S 3776.20E 5048.27 11029.43 8801.90 8740.80 7 35 S 49.01 E .33 3721.17S 3785.92E 5060.70 11122.97 8894.64 8833.54 7 25 S 48.08 E .21 3729.26S 3795.08E 5072.54 11217.38 8988.28 8927.18 7 12 S 46.51 E .32 3737.41S 3803.92E 5084.11 11310.38 9080.54 9019.44 7 18 S 44.71 E .27 3745.63S 3812.32E 5095.32 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5344.49 FEET AT SOUTH 45 DEG. 30 MIN. EAST AT MD = 11310 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 116.93 DEG. TIE-IN SURVEY AT 6594.06' MD LAST SURVEY STATION AT 11310.38' MD Sn~.RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) MILNE POINT / MPK-33 500292272900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 4/97 DATE OF SURVEY: 012197 JOB NUMBER: AK-EI-70019 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6594.06 4902.76 4841.66 2595.67 S 2564.15 E 1691.30 7594.06 5554.88 5493.78 3130.85 S 3095.11 E 2039.18 347.88 8594.06 6401.51 6340.41 3437.24 S 3509.79 E 2192.55 153.37 9594.06 7382.00 7320.90 3575.47 S 3635.35 E 2212.07 19.52 10594.06 8370.79 8309.70 3682.04 S 3739.47 E 2223.27 11.20 11310.38 9080.54 9019.44 3745.63 S 3812.32 E 2229.84 6.58 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SP~.RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) MILNE POINT / MPK-33 500292272900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 4/97 DATE OF SURVEY: 012197 JOB NUMBER: AK-EI-70019 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6594.06 4902.76 4841.66 6687.79 4961.10 4900.00 6849.40 5061.10 5000.00 7011.67 5161.10 5100.00 2595.67 S 2564.15 E 2649.62 S 2613.86 E 2744.35 S 2698.37 E 2840.85 S 2782.17 E 1691.30 1726.69 35.39 1788.30 61.61 1850.58 62.28 7172.99 5261.10 5200.00 7322.49 5361.10 5300.00 7462.73 5461.10 5400.00 7602.71 5561.10 5500.00 7738.35 5661.10 5600.00 2935.40 S 2866.31 E 3012.32 S 2946.37 E 3074.80 S 3022.23 E 3134.51 S 3099.88 E 3188.81 S 3173.64 E 1911.89 61.31 1961.39 49.51 2001.63 4'0.23 2041.61 39.99 2077.25 35.64 7866.71 5761.10 5700.00 7989.21 5861.10 5800.00 8107.66 5961.10 5900.00 8222.46 6061.10 6000.00 8334.33 6161.10 6100.00 3233.82 S 3240.30 E 3272.70 S 3299.38 E 3307.16 S 3352.63 E 3339.20 S 3398.94 E 3370.81 S 3437.84 E 2105.61 28.36 2128.11 22.50 2146.56 18.45 2161.35 14.79 2173.23 11.88 8443.81 6261.10 6200.00 8551.16 6361.10 6300.00 8656.58 6461.10 6400.00 8760.68 6561.10 6500.00 8864.01 6661.10 6600.00 3400.74 S 3470.79 E 3427.30 S 3499.36 E 3450.16 S 3523.58 E 3469.74 S 3544.82 E 3487.29 S 3563.97 E 2182.71 9.48 2190.06 7.35 2195.48 5.42 2199.58 4.10 2202.91 3.32 8966.30 6761.10 6700.00 9067.64 6861.10 6800.00 9168.58 6961.10 6900.00 9269.54 7061.10 7000.00 9370.65 7161.10 7100.00 3502.28 S 3579.36 E 3514.84 S 3589.87 E 3526.59 S 3596.94 E 3538.15 S 3604.61 E 3549.86 S 3613.89 E 2205.20 2.29 2206.54 1.34 2207.48 .94 2208.44 .96 2209.55 1.11 9471.80 7261.10 7200.00 9572.93 7361.10 7300.00 9674.07 7461.10 7400.00 9775.23 7561.10 7500.00 9876.43 7661.10 7600.00 3561.60 S 3623.56 E 3573.08 S 3633.30 E 3584.51 S 3643.19 E 3595.96 S 3653.39 E 3607.53 S 3663.77 E 2210.70 1.15 2211.83 1.13 2212.97 1.14 2214.13 1.17 2215.33 1.20 9977.64 7761.10 7700.00 10078.85 7861.10 7800.00 10180.01 7961.10 7900.00 10281.08 8061.10 8000.00 10382.12 8161.10 8100.00 3619.10 S 3674.19 E 3630.59 S 3684.71 E 3641.66 S 3695.24 E 3651.91 S 3705.76 E 3661.64 S 3716.49 E 2216.54 1.21 2217.75 1.21 2218.91 1.16 2219.98 1.07 2221.02 1.04 10483.19 8261.10 8200.00 3671.31 S 3727.46 E 2222.09 1.06 PAGE 5 Sn~'RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION (ALASKA) MILNE POINT / MPK-33 500292272900 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 4/97 DATE OF SURVEY: 012197 JOB NUMBER: AK-EI-70019 KELLY BUSHING ELEV. = 61.10 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 10584.26 8361.10 8300.00 3681.09 S 3738.41 E 2223.16 10685.32 8461.10 8400.00 3690.69 S 3749.37 E 2224.21 10786.32 8561.10 8500.00 3699.76 S 3760.34 E 2225.22 10887.32 8661.10 8600.00 3708.70 S 3771.26 E 2226.22 10988.26 8761.10 8700.00 3717.60 S 3781.81 E 2227.16 1.07 1.05 1.01 .99 .95 11089.14 8861.10 8800.00 3726.34 S 3791.83 E 2228.04 11189.98 8961.10 8900.00 3735.05 S 3801.43 E 2228.88 11290.78 9061.10 9000.00 3743.86 S 3810.56 E 2229.68 11310.38 9080.54 9019.44 3745.63 S 3812.32 E 2229.84 .88 .84 .80 .16 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS TIE-IN SURVEY AT 6594.06' MD LAST SURVEY DEPTH AT 11310.38' MD [:] I:! I I--I-- I ~ G S G: FI~JI r- E S WELL LOG TRANSMITrAL To: State of Alaska May 7, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPK-33 AK-MM-70005 The technical data listed below is being submitted herewith. Please acknowledge receipt by remming a signed copy of this transmittal letter to the attention off Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted LIS Tape with verification listing. APl#: 50-029-22729-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I::! i I--I-- I I~ G WELL LOG TRANSMITTAL To: State of Alaska April 30, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPK-33, AK-MM-70005 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPK-33: 2"x 5" 1MD Resistivity and Gamma Ray Logs: 50-029-22729-00 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22729-00 2"x 5" MD Neutron and Density Logs: 50-029-22729-00 2"x 5" TVD Neutron and Density Logs: 50-029-22729-00 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia _ . ~-~. ;v '~-~ ' 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10943 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 4/1 5/97 Well Job # Log Description Date BL RF Sepia LIS Tape MPK-06 L"",/~7: '? ~'~'.~ ,..'~' ~? 97127 GR/CCL (PDC) 970112 1 MPK-33 '"/~-' '.'7 ( ,-¢.: - ~' %,..,2 971 26 GPJCCL DEPTH LOG 9701 29 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 ~,.~r"cj ~ t!l iii ,I,I~[~1 ~-~ GeoQuest 500 w. International Airport [toad Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10814 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 2/21/97 Well Job Cf Log Description Date BL RF Sepia LIS Tape M PF-21 ULTRASONIC IMAGER 9 701 04 I 1 MPF-21 GR-CCL CORRELATION 9 701 05 I 1 MPF-21 CEMENT BOND LOG 9701 04 1 1 MPF-21 TDT GRAVEL PACK LOG 9701 08 1 1 MPF-21 9 5/8" PACKER RECORD 9701 05 I 1 MPU K-33 STATIC TEMPERATURE PRESSURE 9 701 2 9 I 1 MPU K-33 BRIDGE PLUG SET 970207 I 1 MPU K-33 GR/CCL DEPTH LOG 9701 29 I 1 MPU F-54 GR/CCL DEPTH LOG 9701 31 I 1 MPH-07 GR/CCL CORRELATION LOG 9 701 21 I 1 MPK-06 PERFORATION RECORD 9 701 1 2 I 1 MPK-06 GR-CCL PRIMARY DEPTH LOG 97011 2 I 1 MPE-17 CEMENT BOND LOG 9 701 07 I 1 MPE-17 COMPLETION RECORD 9 701 2 7 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 ~dW~rd J. Behm~ Jr. Asset Team Leader HeAuy oll Te.%m Wesuern R~g£on OXY USA Inc. 6 Desta Drive, Suite (5000, Midland, TX 79705, P.O. Box B0:250, Midland, TX 79710-0250 Telephone 915685-5B00 Fax 915 1-385-5754 Phone 915 ~5-5673 FAX 915 685-5931 January 17, 1997 Alaska oil and Gas Conservation Commission ~,'. No. 907 276-7542 ktnention' Mr. Bob Crandall Reference: Applicatkon ~or Spacing Excep%ion For the Milne Point Unit K-33 Well Dear Mr. Crandait' .:KY USA !nc., as affected parEy, has no objection to the drilling o~ the Miine ?oi~t K-33 Well as proposed in Lance Spencer's reques~ to you dated October 4, 1996. Should you have any questicns, please give me a call an 915 685-5673. Thar~k you. EJB/esm RECEIVED 17 199i' Respectfully, ~.,-~, - ~ . Ed Behm, Jr. Asset Team Leader Heavy Oil Team Alasl,m 011 & Gas Cons, Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATION OF BP ) EXPLORATION (ALASKA) INC. for an ) order granting an exception to spacing ) requirements of Title 20 AAC 25.055 ) to provide for the drilling of the BP Milne ) Point Field MPK-33 exploratory oil well. ) ) Conservation Order No. 386 BP Exploration (Alaska), Inc. ~MPK-33 January 14, 1997. IT APPEARING THAT: BP Exploration (Alaska), Inc. submitted an application dated December 23, 1996 requesting exception to 20 AAC 25.055(a)(1) to allow completing the BP Milne Point Field MPK-33 oil well to a location closer than 500 feet from a quarter section line in an undefined oil pool within the Sag River formation. . Notice of opportunity for public heating was published in the Anchorage Daily News on December 27, 1996 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: The BP MPK-33 well as proposed will be a deviated hole drilled from a surface location 3536' from the south line (FSL) and 2056' from the east line (FEL) of Section 3, T12N, R11E, Umiat Meridian (UM) to a proposed Sag River Formation producing location 5067' FSL and 3511' FEL of Section 11, T12N, R11E, UM. 2. Occidental Petroleum Corporation, the only offset owner, has been duly notified. . An exception to 20 AAC 25.055(a)(1) is necessary to allow completion of this well within the Sag River Formation. CONCLUSION: Granting a spacing exception to allow the completion of the BP MPK-33 well within the Sag River Formation as proposed will not result in waste nor jeopardize correlative rigbXs. _ Conservation Order No. 386 January 14, 1997 Page 2 NOW, THEREFORE, IT IS ORDERED: BP Exploration (Alaska), Inc.'s application for exception to 20 AAC 25.055 for the purpose of completing the Milne Point Field MPK-33 well as proposed is approved. DONE at Anchorage, Alaska and dated January 14, 1997. David W Johnston, Chairman'"'- \ . Alaska Oil an~tlon Commission Mary C. Marshburn, Commlss~oner Alaska Oil and 'Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of v, citten notice of tile entry of an order, a person affected by it may file with the Conmfission an application lbr rehearh~g. A request /'or reheanng must be receivcd by 4:30 PM on the 23rd day/bllovdng the date of the order, or next working day if a holiday or weekend, to be timciv filed. The Conmfission shall grant or refuse the application in whole or in part within 10 days. The Conmfission can refitse an application bv not acting on it within the 10-day period. An affected person has 30 days t¥om the date the Cmmnission refuses the application or mails (or otherwqse distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. ~q~ere a request tbr reheanng is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearin~ was ,filed). MEMORANDUM TO: David Jol~~on," Chairman;;='.' THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 8, 1997 Blair Wondzell, P. I. Supervisor FROM: Lou Grimaldi, ~,.,. SUBJECT: Petroleum Inspector FILE NO: EWQJAHEE.D©C Diverter inspection Nabors 27E BPX well #MPK-33 Kuparuk River Field PTD 96-202 Thursday, January 8, 1997: I traveled to F Pad in the Kuparuk River field to witness the Diver[er function test on Nabors 27E which was preparing to drill surface hole on BPX well #MPK-33. The rig was ready when I arrived and the function test of the Diver[er assembly went well. The twenty inch annular preventer had a closure time of 30 seconds which is fair for this equipment. The accumulator had a recharge time of 1 minute 11 seconds. The gas detection system was tested and failures were found in both the Methane and H2S systems. ! walked the vent line and found a well laid out line. This rig is still using a 10" vent line and I advised Richard Larkin (Nabors Toolpusher) that changes in the regulations when in effect will make this line size unacceptable. The Methane detectors were fixed this evening. The H2S detectors were found to have bad power supply and will have a new supply before drilling out of the surface shoe. SUMMARY: I witnessed the Diver[er function test on Nabors 27E. Two failures noted. Attachments:. EWQJAHEE.XLS cc: Randy Thomas/Mike Miller (Prudhoe Bay drilling) Drlg Contractor: Operator: Well Name: Location: Sec. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Nabors Alaska BPX MPK-33 11 T. 12N R. Operation: Rig No. Development 27E PTD # Date: X Exploratory: 96-202 Rig Ph. # Pete Wilson Oper. Rep.: Rig Rep.: 11E 1/8/97 659-4373 Richard Larkin Merdian UM TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P Reserve Pit: N/A (Gen.) DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Turns Targeted / Long Radius: Well Sign: Drlg. Rig: Flare Pit: 20 Yes P 10 129 P P P P P P N/A in. in. ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 3OOO 1850 min. 21 1 min. 11 Eight Bottles psig psig sec. sec. MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: 2400 average psig Light Alarm P P GAS DETECTORS: Methane Hydrogen Sulfide: P P P P Light Alarm F F F F DIVERTER SCHEMATIC MANIFOLD ~ BUILDING PITS MOTORS NORTH 125' ! PIPE SHED i WIND DIRECTION Non Compliance Items 2 Repair Items Within N/A Day (s) And contact the Inspector @ 659-3607 Remarks: H2S detectors down for power supply. Methane detector in pits inop. Repair before spudding. Distribution orig. - Well File c- Oper/Rep c- Database c - Tdp Rpt File c- Inspector AOGCC REP.: OPERATOR REP.: EWQJAHEE.XLS Louis R. Grimaldi Pete Wilson DVTRINSP.XLT (REV. 1/94) STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION CO~vIMISSION APPLICATION FOR SUNDRY APPROVAL~ [] Abandon [] Suspend [] Plugging [] Time Extension ~,Perforat~ Type of Request: [] Vadance'[] Other [] Alter Casing [] Repair Well [] Pull Tubing [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Spacing Exception 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3536' NSL, 2056' WEL, SEC. 3, T12N, R11E (Not Final) At top of productive interval 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) Plan RTE = 60.9' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-33 9. Permit Number 10. APl Number 50- ~,~ 5079' NSL, 3536' WEL, SEC. 11, T12N, R11 E At effective depth At total depth 5067' NSL, 3511' WEL, SEC. 11, T12N, R11E 11. Field and Pool Milne Point Unit / Sag River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length feet feet feet feet Plugs (measured) Junk (measured) Size Cemented MD TVD ORIGIk!AL Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) RECEIVED DEC 2. 6 1996 Naska 0il & Gas Cons, C0rnnlJss~0tl Anchorage 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Date approved Contact Engineer Name/Number: Lance Spencer, 564-5042 Prepared By Name/Number: Kathy Campoamor, 564-5122 17. I hereby certify that the fore_going is true ,~nd corr~lct~ to the best of my knowledge T'rmSdnofield Title Senior Drilling Engineer // Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity BOP Test~ Location clearance Mechanical Integrity Test__ Subsequent form required 10- Approved by order of the Commission Llriglnal 5~9ncu -,~ 0avid W. Johnstor, Form 10-403 Rev. 06/15/88 Approve~i~sioner Return.ed Submit In Triplic~tte BP EXPLORATION 900 East Benson Boulevard Anchorage, Alaska 99519-6612 (907)561-5111 October 4, 1996 David W. Johnston, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 RE: Request of Exemption to Provisions of 20AAC 25.055 and Conservation Order 173 Rule #3 for MP K-3~.5 Dear Commissioner Johnston, BP Exploration (Alaska), Inc. hereby applies for an exemption to the provisions of 20 AAC 25.055 and Conservation Order 173 Rule #3 for MP K-33 Well (the well), for which the following is proposed' 1. Surface Location: 3536 NSL 2056 WEL Sec 03 T12N R11E UM., AK 2. Sag Target Location: 5079 NSL 3536 WEL Sec 11 T12N R11E UM., AK 3. Bottom Hole Location: 5037 NSL 3511 WEL Sec 11 T12N R11E UM., AK The owners and operator of all governmental quarter sections directly and diagonally offsetting the proposed location of the well are BP Exploration (Alaska), Inc., and Occidental Petroleum. The plat required by the regulation is attached as Exhibit 1. The verification required by the regulation is attached as Exhibit 2. Copies of the notification to the owners and operators, as well as the required information with respect to the mailing are attached in the package designated as Exhibit 3. Thank you for you assistance in this matter. Please direct any questions to Tom Niswander at 564-5472 or me at 564-5042. Respectfully, Lance Spencer cc BPX OXY BP EXPLORATION 900 East Benson Boulevard Anchorage, Alaska 99519-6612 (907)561-5111 October 4, 1996 Bob Crandall ' Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Application requesting Spacing Exemption for MP K-33 to provisions of 20 AAC 25.055 and Conservation Order 173 Rule #3. Dear Mr. Crandall, The MP K-33 well is a planned producer into the Sag River Formation in the NWl4 of Sec 11 T12N, R11E within ADL lease 375132. BP Exploration (Alaska), Inc. hereby applies for an exemption to the provisions of 20 AAC 25.055 and Conservation Order 173 Rule #3 for MP K-33 Well (the well), for which the following is proposed: 1. Surface Location: 3536 NSL 2056 WEL Sec 03 T12N RllE UM., AK 2. Sag Target Location: 5079 NSL 3536 WEL Sec 11 T12N R11E UM., AK 3. Bottom Hole Location: 5037 NSL 3511 WEL Sec 11 T12N RllE UM., AK The well MP K-33 will be completed with an electrical submersile pump. The surface location of MPK-33 is located in the NE/4 of Sec 3 which is within ADL lease 375133. The target and bottom hole locations are located in the NWl4 of Sec 11 which is within ADL lease 375132 as indicated in the enclosed exhibits. The proposed target and bottomhole locations are within the NWl4 of Sec 11 T12N, R11E but are in close proximity to the western and northern boundaries of this quarter section. The spacing requirements of 20 AAC 25.055 and Conservation Order 173 Rule #3 do not allow without exemption the ddlling of a well closer than 500 feet to any quarter section line. This request for exemption is being sought to allow for the optimum placement of the well MPK-33 within a fault block of the Sag River formation within the NWl4 of Section 11. The owners and operator of all governmental quarter sections directly and diagonally offsetting the proposed target and bottom hole location of the well are BP Exploration (Alaska), Inc., and Occidental Petroleum. The plat required by the regulation is attached as Exhibit 1. The verification required by the regulation is attached as Exhibit 2. Copies of the notification to the owners and operators, as well as the required information with respect to the mailing are attached in the package designated as Exhibit 3. As indicated by the information enclosed in Exhibit 1, Exhibit 2, and Exhibit 3 w e verify these facts to be true and that the plat portrays the pertinent and required data. We also feel that this addresses the requirements of the provisions in 20 AAC 25.055 and Conservation Order 173 Rule #3. Thank you for you assistance in this matter. Please direct any questions to Tom Niswander at 564-5472 or me at 564-5042. Respectfully, Lance Spencer cc BPX OXY BP EXPLORATION 900 East Benson Boulevard Anchorage, Alaska 99519-6612 (907)561-5111 October 4, 1996 Occidental Petroleum Ed Behm 6 Desta Drive Suite 6000 Midland, TX RE: Request for Spacing Exemption for lVP K-33 to provisions of 20 AAC 25.055 and Conservation Order 173 Rule #3. Dear Mr. Behm Pursuant to the provisions and requirements of 20 AAC 25.050 (b) BP Exploration (Alaska) Inc. hereby gives notice of a request to the Alaska Oil and Gas Conservation Commission for an exemption to the provisions of 20 AAC 25.055(a) 1, 20 AAC 25.055 and Conservation Order 173 Rule #3 for MP K-33 Well (the well). Specifically, the exemption location applied for will be as followed:: , Surface Location: Sag Target Location: Bottom Hole Location: 3536 NSL 2056 WEL Sec 03 T12N R11E UM., AK 5079 NSL 3536 WEL Sec 11 T12N R11E UM., AK 5037 NSL 3511 WEL Sec 11 T12N RllE UM., AK A copy of the request is attached. Very truly yours, Lance Spencer enc. K-21/!~ K-02 /F 4- + K-01 i/O K-10 (K-Ni) P96~48 K-06 /M K-09 i/N + POL ?8/// Sec Line Tie ~-05 /K 4- K-10 /XX / '-'~'K-13 M K.13 /L/plan actual co + K-14 i/R K- ~o K-18 /H + t 4-- + K-21 i/G K-25 i/J+ +Ca adel K-22 i/T 1 K~38 /A K'26 i/Q K-30 /D K-3 CD actual +K-37 / E K-33 /I ~ ++ 1768 04 89o15'16" MPK-33(P4) 2 ~,, 3" Bottom Hole 116°1 1 ,Zi/ E-17i/ E~14 MPK-33(P4) Sag River Tar POL Sec Line Tie + K-34 /C + K-42 i/S K-41 /P + O/ lzS-N + ID/! 9D-~t + H/ g ~-:fl + CI/08-H + 9Z.'Z961-009=,,k 8Z'lzZ888cj=x co alOH u~o~,~,o8 c~ (~d)SS-),ld IAI ~ro + O/ 08-N 881.1. "-'*' .~e^!bl 5aS V/ 88'H Ueld/q/ 8 lentoe 8 K-( /M K-13 actual 3 /L/plan 4'- 1744 89°15'16" K~21 i/G Cascade' K-38 /A K-33 /I 04 T MPK~33(P4.'~ ,~ Sag River Target ~o X=588350,00 Y=6001980,00 28 116':17'13'' MPK-33(P4) Bottom Hole K-2,! 1138 i/T K-30 /D + K-30/D + ~de Ti~ + K-18 /H K-14 itR + K-26 i/Q ]ctual + K-34 /C 4- K-42 ilS K-41 /P + EXHIBIT2 VERIFICATION OF APPLICATION FOR SPACING EXCEPTION MILNE POINT K-33 L. SPENCER, Ddlling Operations Engineer, BP Exploration (Alaska) Inc., does hereby verify the following: 1. I am acquainted with the application submitted for the drilling of Milne Point K-30 Well.. 2. I have reviewed the application submitted for the exemption to 20 AAC 25.055, Conservation order 173 Rule #3 and all the facts therein are true. 3. I have reviewed the plat attached as exhibit 1 and it correctly portrays pertinent and required data. DATED at Anchorage, Alaska this ~.-~ day of ~(..(~,LC..n~,~1996. STATE OF ALASKA THIRD JUDICIAL DISTRICT SUSCRIBED AND SWORN TO before me this 996. day of AND FOR ALASKA My commission expires: ~ P 5~4 009 522 .~ Postal Ser¢ice Receipt for Certified Mail No Insurance Coverage Provided. Do nol use for Inlernational Mail (See reverse) St[eel & Number Post Office, Sla:e, & ZIP Code /4, .,'/,.... ,/ 7-X ?e Special Deliver/Fee Restricted Delivery Fee Return Receipt Showing to ',¥,~om ~, ~ , /' ?~ o SENDER: · Complete items I and/or 2 for additional services. · 'Complete items 3, 4a, and 4b. · Print your name and address on the reverse of this form so that we can return this card to you. · 'Attach this form to the front of the mailpiece, or on the back if space does not permit. ~ "Write'Return Receipt Requested' on the mailpiece below the article number. · The Return Receipt will show to whom the article Was delivered and the date delivered. I also wish to receive the followin9 services (for an extra fee): W 1. [] Addressee's Address ,:> 2. [] Restricted Delivery ~ Consult postmaster for fee. .-~ 3. Article Addressed to: /'~. , ¢? /- ,-- ,/ 7'-/ '?~7o y'= 5. Received By: (Print Name) 6. Signatu/~e: (Addressee or Agent) PS Fo~ 3811, De~emb~r 1994 4a. Article. Number 4b. Service Type [] Registered '[~Cedified [] Express Mail [] Insured [] Return Receipt for Merchandise [] COD 7. Date of Delivery ' 8. Addressee's Address (Only if requested and fee is paid) Domestic Return Receipt TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION December 27, 1996 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Tim Schofield, Senior Drilling Engineer BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well No. Company Permit No. Surf Loc Btmhole Loc Milne Point Unit MPK-33 BP Exploration (Alaska) Inc. 96-202 3536~SL, 2056'WEL, Sec 03, T12N, R11E, UM 5067~SL, 3511'WEL, Sec 11, T12N, R11E, UM Dear Mr Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance ~vith 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ckerman Babcock Commissioner BY ORDER OF THE COMMISSION dlf/encl c: Dept ofFish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill [lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen~ [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 60.9' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 375132 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3536' NSL, 2056' WEL, SEC. 3, T12N, R11E (Not Final) Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 ~.~,5202' NSL, 3777' WEL, SEC. 11, T12N, R11E MPK-33 At total depth 9. Approximate spud date Amount $200,000.00 5067' NSL, 3511' WEL, SEC. 11, T12N, R11E 01/03/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 375133, 1769'I No Close Approach 2560 11525' MD / 9245' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 500' Maximum Hole Angle 54.37° Maximum surface 3673 psig, At total depth (TVD) 9200' / 4593 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 6582' 31' 31' 6613' 4938' 1692SXPF'E',221 SX'G',95sxPF'C" 8-1/2" 7" 26# L-80 Btrc 11494' 30' 30' 11525' 9306' 511 sx Class 'G' i19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate ProductionRECEIVED Liner DEC 2 6 1996 Perforation depth: measured AJEJJ(J OJJ & G~I~ {~ong. true vertical Anchora~ 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Lance Spencer, 564-5042 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is true and co(rqct to the best of my knowledge Signed .,;'~1 Title Senior Drilling Engineer Date J'~ ~.. Tim Schofield . / Commission Use Only c~.. ~,.0 ~ 50- ~ ~ .. ~-~,.~ ~ & c~ .. 0 ~ /-~, --,~'J --~ ~ for other requirements Conditions of Approval: Samples Required [] Yes ,[~ No Mud Log Required [] Yes J~No Hydrogen Sulfide Measures ]~Yes [] No Directional Survey Required J~Yes [] No Required Working Pressure for BOPE [] 2M; []3M; J~ 5M; [] 10M; [] 15M Other: 0riglnal Signed By by order of Approved By Tuckerman Babcock Commissioner the commission Date y Form 10-401 Rev. 12-01-85 Submit In Triplicate MPU K-PAD WELL 33 DOWNHOLE LOCATIONS 12/24/96 ITEM NAME ~Iv~NTS ALASKA STATE PLANE ZONE 4 (NAD 27) DECIMAL DEGREES (NAD 27) S & E SEC UNE OFFSETS SECTION, TOWN., NE/~EST SECTION UNE OFFSETS NO. Y X LATITUDE (N°) ; LONGITUDE 0N°) FSL FEL RANGE, UMIAT, AK DIST. UNE DIST. UNE 1 K-33 /I Plan Downhole Loc. 6,002,100.00' 588,107.00' 70.4155515° 149.2823787° 5202 3777 SEC 11 T12N R11E 77 N 1502 W 2 K-33Sag River Target Plan Downhole Loc. 6,001,980.00' 588,350.00' 70.4152158° 149.2804113° 5080 3536 SE_~C11 T12N R11E 200 N 1744 W 3 K-33 Bottom Hole Location Plan Downhole Loc. 6,001,967.76' 588,374.78' 70.4151816° 149.2802106° 5067 3511 SEC 11 T12N R11E 213 N 1769 W Notes: Coordinates shown are North American Datum 1927 (NAD 27). F. Robert Bell & Assoc. Jel'f Cotton 564-4969 File Name: MPKBH's.xls Wk Sht 1 2/24/96 Shared Services Drilling Contact: Lance J. Spencer I Well Name: IMP K-33 Well Plan Summary 564-5159 I Type of Well (producer or iniector): I Kuparuk Producer Surface Location: 3536 NSL 2056 WEL Sec. 03 T12N RllE UM., AK Kuparuk Target 5202 NSL 3777 WEL Sec. 11 T12N RllE UM., AK Location: Bottom Hole 5067 NSL 3511 WELSec. 11 T12N R11E UM.,AK Location: I AFE Number: 1337036 I I Rig: I Nabors 27-E I IWell Design (conventional, slimhole, I Milne Point Ultra Slimhole Longstring 9- etc.)' 15/8", 40# Surface X 7", 26# Longstring Formation Markers' Formation Tops MD TVD (bkb) Pore Pressure (EMW,Psi) Base Permafrost 1 880 1 861 8.3 ppg, 803 psi NA 6 051 45 61 8.3 ppg, 1968 psi CA 6 2 9 2 4 7 01 8.3 ppg, 2029 psi CB 6403 4766 8.3 ppg, 2131 psi BaseOB 6463 4801 8.3 ppg, 2147 psi TopHRZ 8655 6471 8.6 ppg, 2894 psi BaseHRZ 8847 6656 8.6 ppg, 2977 psi TKLB 8 91 4 6 721 9.0 ppg, 3006 psi TKUP/UD 9063 6866 9.4 ppg, 3213 psi TKUC 9 2 0 5 7 0 0 6 9.9 ppg, 3607 psi TKC1/TARGET 9 2 6 5 7 0 6 6 9.9 ppg, 3638 psi TKUB/B8 931 6 71 1 6 9.9 ppg, 3663 psi TKB7 9 3 31 71 31 9.9 ppg, 3742 psi TKUA 9533 7331 9.9 ppg, 3774 psi IV, !:::t,, I:;: I V ! TMLV 9 6 2 3 7 421 9.9 ppg, 3820 psi TKNG 9810 7606 9.9 ppg, 3916 psi TSGR 1 1 31 9 91 01 9.6 ppg, 4543 psi TSHU 1 1394 9176 9.6 ppg, 4581 psi TElL 1 1485 9266 9.6 ppg, 4626 psi Anchorag~ Total Depth _+ 1 1 5 2 5 9 2 7 6 9.6 ppg, 4631 psi D Casinq/Tubing Pro ram' Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btrc 6582 31/31 6613/4938 8-1/2" 7" 26# L-80 btrc 11494 30/30 11525/9306 The internal yield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the Sag sand at + 9200 TVDSS In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +9200 TVDSS. The maximum anticipated surface pressure in this case is 3673 psi assuming a reservoir pressure of 4593 psi, well below the internal yield pressure rating of the 7" casing. Note 1: If necessary the surface casing setting depth will be adjusted and will be set above the Schrader Bluff. If the drilling mud weights of 10.5 ppg or higher are required to control gas hydrates immediately contact the Drilling Superintendent before drilling ahead into the Schrader Bluff. In case the surface casing setting detph is revised and is set above the Schrader Bluff a 7" drilling liner will be then be set after above the Sag after drilling the Kuparuk interval. Logging Program: Open Hole Logs: None Surface MWD Directional LWD (GR/EWR4/ROP)to TD.from surface to TD of surface hole. Real Time N/ Production Cased Hole Logs: Mud Logging MWD Directional from 9-5/8 shoe and LWD (GR/EWR4/CNP/SLD/ROP) from surface shoe to T D. Real Time N/A Mud Loggers and samples are NOT required. MWD GR: EWR4: CNP: SLD: ROP: Directional: Inclination and Azimuth Gamma Ray Electromagnetic Wave Resistivity 4 (Four Depths of Investigation) Compensated Neutron Porosity Stabilized Litho Density Rate of penetration Mudloggers are NOT required for this well. Mud Program: Special design considerations Special attention should be given to, gravel, clay, hydrate, and coal intervals in the surface hole. Running gravel, sticky clays below the permafrost, gas gut mud due to hydrate formation, excessive fill on connections, tight coal sections and stuck pipe have been encountered in previous surface holes on K-Pad. Prior to spudding a complete review of the K-Pad drilling hazards is required. Preventative measures such as more frequent short trips, viscosity and mud weight control, Iow mud temperatures, controlled drilling rates, and lower flow rates should be employed to mitigate problems and lost time in the surface hole. HYDRATES Hydrates are present on K-Pad and must be managed safely. Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 1 00 1 5 8 1 0 9 8 to to to to to to to 10.2 or 50 35 15 30 10 15 less LSND freshwater mud Production Mud Properties: Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 4 0 1 0 3 7 8.5 6 - 8 to to to to to to to 11.0 50 15 10 20 9.5 4-5 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: KOP: 500' Maximum Hole Angle: 54.37° Close Approach Well: (No Shut Ins) All wells may remain flowing while drilling K-33. REICE VED DEC ?_ G 1996 Naska 0il Gas Cone. 00mmism0. Anchorage Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations 1. The base of the Permafrost for all wells located in the Milne Point Unit is +1,850' TVD. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 2. There are +_12 wells on Milne Pt. 'K' Pad. There may be additional unidentified wells within one quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 3. The wastes to be disposed of during drilling operations can be defined as "DRILLING WASTES". 4. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. O[C 'xe3e3 6 , . . , . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. MP K-33(Kup) Proposed Summary of Operations Review Pre-Spud Checklist RP-Surface Hole VI.0 pages 1-3. prior to spud. Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5A Wellhead on conductor as well as a nipple to aid in performing potential wellhead stability cement job. Prepare location for rig move. MIRU Nabors 27E drilling rig. Review RP-Surface Hole VI.0 pages 1-3. prior to spud. NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisior. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Advise Rig Team to proceed with Extreme Caution prior to and while drilling the hydrate interval. Run Directional MWD from surface to 12-1/4" TD. Review RP-Surface Hole VI.0 pages 1-3. prior to spud Run and cement 9-5/8" casing. Complete the surface casing cementing check list. ND 20" Diverter, NU and Test 13-5/8" BOP MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 10' of new formation. Perform LO to a maximum of 12.5 ppg as per Recommended Practices Manual. Record pressure versus cumulative volume for LOT test for the well file. Drill 8.5" hole to TD as per directional plan. Sufficient footage should be drilled. As aminimum of 150' of production rat hole in the 7" casing between between the base of the Sag sand and PBTD is required. Run and Cement 7" Casing. Insure that a short joint is run in the 7" casing approximately three joints above the top of the Kuparuk and a short joint is run above the Sag. Displace cement with 8.4 ppg source water and enough diesel to cover from the base of permafrost to surface (+-2100' MD). Test casing to 3500 psig. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. Review Recommended Practice for Running Tubing Std Tbg Rng V3.2 Review Milne Point Unit ESP Running Recommended Practice RP: Run ESP/PKR: DBR/JDP -5-26/94 Version 0.0 MIRU Nabors 4ES. ND dry hole tree, NU & Test BOPE to 5000 psig. PU and RIH with clean out assembly on 2-7/8" tubing. Cleanout to PBTD. Displace hole with 10.4 ppg kill weight brine. PU and RIH with perforating guns on electric line ( The perforating proceedure will be distributed later with the selected perforation intervals once they are determined). POOH with perforating guns on E-line. PU and RIH with 2-7/8" EUE 8RD tubing with GC 4100 Electric Submersible Pump (ESP) Completion.. Set 2 way check. ND BOPE and test tree. Pull two way check, freeze protect, set BPV, close valves. Test tree RDMO Nabors 4ES completion rig. DRILLING HAZARDS AND RISKS: HYDRATES K-02, K-05, K-17, K-25, K-38, K-39 and encountered hydrates while drilling the surface hole. Severly gas cut mud, excessive connection gas, flow on connections and other problems can occur while during the surface hole on K-Pad and are directly attributed to gas hydrates. In addition problems can develop as a result of measures designed to lessen to effects gas. It is important to recognize what problems might develop while fighting gas hydrates and have plans in place to mininimize them. Plans should be made in advance prior to spudding the surface hole to midigate to potential risks and minimize the nonproductive time involved in managing hydrates. The measures are necessary to lessen to effects of gas hydrates: Increased mud weights Low drilling fluid temperatures Reduced ROP's for control drill rates Controled ciriculating and drilling fuild rates Note: If necessary the surface casing setting depth will be adjusted and will be set above the Schrader Bluff if gas hydrates are severe. If the drilling mud weights of 10.5 ppg or higher are required to control gas hydrates immediately contact the Drilling Superintendent before drilling ahead into the Schrader Bluff. In case the surface casing setting detph is revised and is set above the Schrader Bluff a 7" drilling liner will be then be set after above the Sag after drilling the Kuparuk interval. Close Approaches There are no close approaches associated with the drilling of MP K-66 however tolerance lines should be carefully monitored and deviations from the proposed wellpath minimized.. Water Injection Currently no water injection wells are present on MP K-Pad Annular Injection Currently annular injection is not permitted on K-Pad while drilling K-33.. Gas Injection Currently no gas injection wells are present on K-Pad Lost Circulation: K-05 experienced lost circulation while drilling the 12-1/4" surface hole at 2250 Md. K-02 , K-05 experienced losses while circulating to condition mud while runninng 7" csg K-05 experienced lost circulation while cementing 7" csg. In every instance losses were minimized by reducing flow rate and conditioning the mud. Stuck Pipe Potential: Running gravels (K-17, K-38), sticky clays (K-02, K-05, K-38, K-39) and coal sections (K- 17) presented tight hole and bridging in (K-17, K-25, K-38),and stuck pipe (K-17 ) while driling the 12 1-4" surface hole. Excessive amounts of reaming were required wile drilling K- 17 and K-25). While running 9-5/8" casing the flowing problems experienced: K-05, hole packing off, tight hole and bridging K-2, K-39. The 9-5/6" casing was stuck in K-05. These problems in some instances were greatly exagerated because of measures taken to manage the gas hydrate problems. Increased torque and drag have been experienced after drilling into Kuparuk so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Formation Pressure: KUPARUKSAND 7000' TVD 3600 PSI 9.9 PPG EMW SAGSand 9200' TVDss 4593 psig 9.6 ppg EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the Sag sand at + 9075 'rVDSS In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +9075 TVDSS. The maximum anticipated surface pressure is 3673 psi in this case assuming a reservoir pressure of 4593 psi, The maximum expected pore pressure for this well is 9.6 ppg EMW (4,953 psi @ 9,075' TVDss). There has been injection in this region from MP K-17, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point K-Pad Data Sheet prepared by Pete Van Dusen for information on K pad and review recent wells drilled on K Pad. MP K-33 (Kup) 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON TWO STAGE CEMENT PROGRAM: ES Cementer located at 2100' md. RECIPROCATION of the CASING STRING is required WHILE CEMENTING. RECIPROCATION of the CASING STRING is required WHILE CEMENTING. Casing Size: 9-5/8" Circ. Temp 60 deg F at 2840' TVDSS. First Stage. Lead and Tail slurries are pumped in the first stage. SPACER: 70 bbls NSCI weight 1 ppg higher than current mud weight. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: 0.25#/sk Flocele WEIGHT: 12.0 ppg APPROX NO SACKS: 742 YIELD:2.17 ft3/sx MIX WATER: 11.55 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. First Stage Lead Cement Volume = The estimated first stage lead cement volume is equivalent to the annular volume calculated from the ES Cementer @ 2100' md to the Schrader NA Top at 6013' md+ 30% EXCESS. TAIL CEMENT TYPE: Premium G ADDITIVES: 2.0% CaCI2 +.15#/sk Flocele WEIGHT: APPROX #SACKS: 221 FLUID LOSS: 15.8 ppg YIELD'1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. 100-150 cc FREEWATER: 0 First StageTail Cement Volume The estimated first stage tail cement volume is equivalent to the annular volume calculated from the the Schrader NA Top @ 6013' to surface TD at 6613' md plus 30% Excess + the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md 9-5/8",40#casing for float joints. Second Stage. Lead and Tail slurries are also pumped in the second stage. MAKE SURE THAT THE SECOND STAGE LEAD CEMENT IS CIRCULATED TO SURFACE BEFORE PUMPING SECND STAGE TAIL. The objective of the Second Stage of the cement program is to make sure cement is circulated to surface. Preparations should be made to continue pumping cement until such time as cement returns are observed at the surface. This volume will likely exceed the annular capacity and the 250% estimated excess. Additional cement should be on hand before the job starts so excess volume should be ordered. LEAD CEMENT TYPE: Type E Permafrost Second Stage Lead Cement Volume = The estimated second stage lead cement volume is equivalent to the annular volume calculated from the Base of the Permafrost located @ 1880' MD to the surface plus 250% excess. SPACER: 75 bbls Water LEAD CEMENTTYPE: Type E Permafrost ADDITIVES: None WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.55 gal/sk APPROX NOSACKS: 9 5 0 THICKENING TIME: Greater than 4 hrs at 50° F. Caution: Do not incorporate FLOCELE "Cello-Flakes" in the Second stage cement slurry. Caution: Do not incorporate FLOCELE "Cello-Flakes" in the Second stage cement slurry. TAIL CEMENT TYPE: Permafrost C Second Stage Taft Cement Volume = The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer @2100' MD to the Base of the Permafrost located @ 1880' md plus 250% excess. SPACER: 75 bbls Water TAIL CEMENTTYPE: Type E Permafrost ADDITIVES: None WEIGHT: 15.6 ppg YIELD: 0.95 ft3/sx MIX WATER: 3.68 gal/sk APPROX NO SACKS: 9 5 THICKENING TIME: Greater than 4 hrs at 50° F. Caution: Do not incorporate FLOCELE "Cello-Flakes" in the Second stage cement slurry. Caution: Do not incorporate FLOCELE "Cello-Flakes" in the Second stage cement slurry. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: The WELLHEAD STABILITY CEMENT WILL BE PUMPED IF THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. ADDITIVES: None WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 1 i.63 gal/sk APPROX NO SACKS: 150 The estimated Wellhead stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the wellhead. CENTRALIZER PLACEMENT: 1. Install one(l) Straight Blade TURBULATOR Centralizers per joint of 9-5/8" casing on bottom 10 joints of casing (required). 2. Install one(l) Straight Blade TURBULATOR Centralizers per joint of 9-5/8" casing on from 2000-2500 feet joints of casing (required).Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. SURFACE CEMENT VOLUME: The objective of the Surface Cement is to insure that cement is circulated to surface. Cement shall be pumped until such time as cement is circulated to surface. Arrangements should be made to insure that sufficient cement is available so that continuous cementing can occur uninterrupted until cement is circulated to surface. Dye shall be introduced into the weighted spacer before the first stage and into the water before the second stage in order to obtain an estimate of annular capacity to that additional cement can supplied if required and adequate excess has been pumped. Once an adequate volume of cement has been circulated to surface immediately begin displacement. OTHER CONSIDERATIONS: After MPK-25 was suspended following problems with the surface casing job. The importance of getting a sucessful cement job on the suface job cannot be stressed enough. There are changes to the spacer, cement volumes and centralizer program on this well. If the cement falls back, do a wellhead stability cement job. MP K-33 (Kup)Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB from TD to 1000' above KUPARUK INTERVAL: CIRC. TEMP: 140° F SPACER: 20 bbls fresh water BHST 170° F at 7040' TVDSS. 70 bbls NSCI mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX Cf SACKS: 0.2% CFR-3, 0.1% HR-5, 0.45% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 511 SACKS THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: , . 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the from 120' below to 1 20' above any potential hydrocarbon bearing sands. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary, CEMENT VOLUME: o Single stage cement volume is calculated to cover 1000 FT MD above the highest potential KUPARUK(TKUPD) production sand + 30% excess. Anadrill Schlumber3er Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907~ 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPK-33(P4) .Field ........ : MILNE ?OINT,KPAD CQmputa~ion.,: Minimum Curvature Units'. ....... : FEE? Surface Lat.,: 70.42542386 N Surface Long.: L49.31140938 W LOCATIONS - ALASKA Zone: 4 Legal Description Surface ...... : 3536 FSL 2056 FEL S03 T12N RllE UM SAG RIVER TAR: 5079 FSL 3536 FEL Sll T12N RIlE UM .'BHL .......... : 5067 FSL 3511 FEL Sll T12N RllE %TM X-Coord Y-Coord 584501.94 6005671,9~ 588107.00 6002100.0 588350.00 6001980.00 588374.70 6001967.76 PROPOSED WELL PROFILE STATION MEASURED INCLN IDENTIFICATION DEPTH ANGLE KB 0,00 0.00 0.00 KOP/BUILD 1/100 500.00 0.00 0.00 600.00 1.00 90.00 BUILD 1.5/100 700.00 2.00 90.00 800.00 3.50 90.00 DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 0.00 -60.90 500.00 439.10 599.99 539.09 699.96 639.06 ~99.84 738.94 900.00 5.00 90.00 CURVE 2/100 1000.00 6.50 90.00 1100.00 6.01 107.87 1200.00 6.15 126.78 BUILD 2/100 1255.50 6.50 136.35 1300.00 7.39 136.35 ~=~==== SECTION DEPART Prepared ..... : 17 Dec 1996 Vert sect az.: 116.93 KB elevation.: 60.90 ft Magnetic Dcln: ~28.282 Sca~e Factor.: 0~99990811 Convergence..: +0.64879788 COORDINATES-FROM WELLHEAD 0.00 0.00 N 0,00 E 0.00 0.00 N 0.00 E 0.78 0.00 N 0~87 E 3.11 0.00 N 3.49 E 7.39 0.00 N 8.29 E (Anadrill (c)96 MPK33P4 3.0b.10 11:58 AM P) 899.56 838.66 14.00 0.00 N 999.06 938.16 22.93 0.00 N 1098.147 1037.57 33.14 1.60 S 1197.92 1137.02 43.59 6 42 S 1253.08 1192.18 49.48 10.47 S FOR STUDY ONLY ALASKA Zone 4 TOOL DL/ X Y FACE 100 ~m ~ 584501.94 6005671.97 HS 0.00 584501.94 6005671.97 90R 0.00 584502.81 6005671.98 90R 1.00 584505.43 6005672.01 90R 1.00 584510.23 6005672.06 90R 1.50 15,70 E 584517 25,72 E 584527 36.36 E 584538 45.63 E 50. lB E . , 1297,26 1236.36 S4.55 14.36 S 53.89 E .64 6005672.15 90R 1.50 .65 6005672.26 l13R 1.50 .31 6005670.78 95R 2.00 584547.63 6005666.07 76R 2.00 584552.23 6005662.07 HS 2.00 584555.99 6005658.22 HS 2.00 PROPOSED WELL PROFILE STATION MEASURED INCLN DIRECTION IDENTIFICATION DEPTH ANGLE AZIMUTH 1400.00 9.39 136.35 1500.00 11.39 136.35 1600.00 13.39 136.35 1682.00 i5.03 136.35 1700.00 15.39 136.35 .... =~== == .......... VERTICAL-DEPTHS SECTION COORDINATES-FROM T%rD SUB-SEA DEPART WELLHEAD 1396.18 i335.28 68.31 24.92 S 63.96 1494.54 1433.64 85.32 37.97 S 76.41 1592.20 1531.30 105.56 53.50 S 91.22 1671,69 1610.79 124,54 68.06 S 105.11 1689.06 1628.16 128.99 71,48 S 108.37 .............. __F:Q__R TUD__Y ONlY ALASKA Zone 4 TOOL DL/ X Y FACE 100 584566.17 6005647.78 HO 2.00 584578.77 6005634,87 HS 2.00 584593.75 6005619.52 ~S 2,00 584607.81 6005605.11 ~S 2.00 584611.10 6005601.73 HS 2.00 584630.81 '6005581.54 HS 2.00 584641.53 6005570.55 HS 2.00 584648.11 6005563,81 ~S 0.00 584659.16 6005552.48 ~S 0.00 584675.296005535.96 MS 2.50 END 2/100 BUILD BASE PERMAFROST BUILD 2.5/100 1800.00 17.39 1850.00 18.39 1879.85 18.39 1930.00 18.39 !~00 20.14 2100.00 22.64 2200.00 25.14 2300.00 27.64 2400.00 30.14 2500.00 32.64 136.35 136.35 136.35 136.35 i36.35 136,35 136.35 136.35 136,35 136.35 1784.99 1724.09 155.60 91.89 S ' 127.85 · 1832.57 1771.67 170.09 103.01 S 138.45 1860.90 1800.00 178.97 109.82 S 144.95 '1908.49 1847.59 193.89 121.27 S 155.87 1974.57 1913.67 215.67 137.98 $ 171.81 2067.67 2006.77 250.07 164.37 S 196.98 E 2159.10 2098.20 288.26 193.67 S 224.9~ E 2248.67 2187.77 330.17 225.83 S 255.61 E 2336..22 2275,32 375,73 . ~60.78 S 288,96 E 2421.57 2360.67 424.85 298.47 S 324.90 E 584700.75 6005509.86 ~S 2.50 S84729.03 6005480.88 HS 2.50 584760.07 6005449.07 HS 2.50 584793.80 6005~14,50 ~S 2.50 584830.17 6005377.23 ~S 2.50 2'600.00 35.14 2700.00 37.64 2B00.00 40.14 2900.00 42.64 3000.00 45.14 136.35 136.3.~ 136.35 136.35 136.35 2504.58 2585.07 2662.90 2737.92 2809,98 2443.68 477.43 338,81 S 2524.17 533.38 381.74 S 2602.00 592.59 427.16 S 2677.02 654.94 475.00 S 2749.08 720.32 525.16 S 363.39 E 584869,11 6005337.32 ~S 2.50 404.34 E 5849'10.54 6005294.87 ~S 2.50 447.67 E 584954.37 6005249.94 ~S 2.50 493.30 E 585000,54 6005202.63 HS 2.50 541.15 E 585048,95 6005153.02. HS 2.50 END 2,5/!00 BUILD NA 3100.00 47.64 3200.00 50.14 3300.00 52.64 3369.09 5437 6051.47 54.37 OA 6291,78 54.37 OB 6403.35 54,37 OB BASE 6463,42 54.37 136.35 136.35 136.35 136.35 136.35 136,35 136.35 136.35 287B.95 2818.05 2'944.69 2883.79 3007.09 2946.19 ~0~8.18 2987.28 46~o.9° ~.~sso. oo 4750.90 4690.00 4815.90 4755.00 4850.90 4790.00 788.60 577.55 S 859.65 632.06 S 933.34 688,60 S 985.72 728.79 S 3041.82 2306,31 S 3226.02 3311.55 3357.60 591.12 E 585099.51 6005101.20 ~S 2.50 643.13 E 585i52,12 6005047.29 HS 2.50 697.06 E 585206.68 6004991.37 ~S 2 50 735.a9 E 585245,47 6004951.62 ~S 2.50 2240.22 E 586767.92 6003391.39 ~S , 0.00 2447.63 S 2375.03 251'3.25 S 2437.62 2548.58 S 2471.33 586904.31 6003251.61 HS 0.00 586967.64 6003186.71 ~S 0.00 587001.74 6003151.77 HS 0.00 ' (Anadrill (c)96 MPK33P4 3.0b.10 11:58 AM P) ~RTPOSED WELL ~ROFILE STATION MEASURED INCLN DIREtTION IDENTIFICATION DEPTH ANGLE AZIMUTH 9-5/8" CASING POINT 6613.42 54.37 136.35 CURVE 2.5/100 7100.77 54.37 136.35 7200.00 51.89 136.16 7300.0C 49.40 135.95 7400.0C 46.90 135.73 VERTICAL-DEPTHS TVD SUB-SEA __ SECTION DEPART 7500.00 44.41 135.49 7600.00 41.91 135.23 7700.00 39.42 134.94 7800.00 36.93 134.62, 7900.00 34.44 134.26 4938.29 4877.39 3472.57 5222.21 5161.31 3846.I3 5281.74 5220.84 3921.04 5345.15 5284.25 3994.09 54~1.87 5350.97 4064.55 8000.0C. 31.95 133.85 8100.00 29.46 133.37 8200.00 26.97 132.82 8300.00 24.49 132.17 8400.00 22.01 13i.38 5481.76 5420.86 5554.70 5493.80 5630.54 5569.64 5709.15 5648~25 5790.37 5'729.45 END 2.5/100 CURVE THRZ BHRZ 8500.00 19.53 8600.00 17.06 8649.42 15.85 8654.61 15.85 8846.92 15.85 130.40 129.14 128.39 128.39 128.39 587~.04 5813.~4 5960102' 5899.12 6048.23 5987.23 6138.21 6077.31 6230.08 6169.18 CURVE 2.5/100 8852.12 15.85 8900.00 14.67 TKLB 89i4.26 14.32 9000.00 12.23 TXUP/UD -'9062.82 10.71 128.39 127.53 127.25 125.24 123.27 6323.57 6262.67' 6418.51 6357.6~ '6465.90 6405.00 6470.90 6410.00 6655.90 6595.00 9100.00 9.8i END 2.5/~00 CURVE 9~90.36 TKUC 9204 . 59 7.68 121.82 116.93 116.93 (Anadrill (c)96 MPK33P4 3.0b.10 11:58 AM 6660.90 6600.00 6707.09 6646..19 6720.90 6660.00 6804.34 6743.44 6865.90 6805.00 6841.59 6930.90 6945.00 . , , 6902.49 6991.80 7005.90 COORDINATES-FROM ALASKA Zone 4 WELLHEAD X Y 2636~79 S 2555.47 E 587086.87 6003064.52 2923.40 S 2828.88 E 587363.48 6002781.05 2980.75 S 2883.76 E 587419.00 6002724.33 3036.42 S 2937.41 E 587473.27 6002669.28 3089.86 S 2989.30 E 587525.75 6002616.44 4132.28 4197.17 4259.09 4317.92 4373.54 3140.97 S 3039.31 E 3189.64 S 3087.37 E 3235.78 S 3133.38 E 3279.32 S 3177.24 E 3320.16 S 3218.88 E 587576.34 6002565.91 587624.94 6002517.79 587671.46 6002472.17 587715.82 6002429.13 587757.91 6002388.77 4425.85 44~4.76 4520.16 4561.98 4600.13 :4634.54 4665.14 4678.84 4680.23 4731.70 O TOOL DL/ 0% FACE 100 HS 0. O0 177L .00 176L 176L 176L 176L . 175L 2.50 175L 2.50 3358.22 S 3258.22 E 587797.68 6002351.16 175L 2.50 3393.45 S 3295.19 E 587835.03 6002316.36 174L 2.50 3425.75 S 3329.70 E 587869.91 6002284.45 174L 2.50 3455.09 S 3361.70 E 587902.24 6002255.48 .173L 2.50 3481.39 S 3391.13 E. 587931.96 6002229.52 172L 2.50 3504.62 S 3417.92 3524.72 S 3442.04 3533.48 S 3452.95 3534.36 S 3454.07 3566.97 S 3495.23 587959.01 6002206.60 587983.35 6002186.77 587994.36 6002178.13 587995.48 6002177.26 ~88037.01 6002145.12 4733.09 3567.86 S 3496 4745.46 357'5.61 S 3506 4748.97 3577.78 S 3509 4768.39. 3589.44 S 3524 4780.78 3596.48 S 3535 3600.04 S 3606.84 S 172L 2.50 170L 2.50 NS 2.50 MS 0.00 HS 0.00 3607.70 .34 E 588038.13 6002144.26 .27 E 588048.15 6002136.62 .11 E 588051.01 6002134.48 .97 E 588067.00 6002123.00 .29 E 588077.39 6002116.08 I~OL 0.00 169L 2.50 169L 2.50 167L 2.50 165L 2.50 4787.37 4801.08 4802.98 3540.87 E' 588083.02 6002112.58 163L 2.50 3552.80 E 588095.02 6002105.92 HS 2.50 3554.49 E 588096.72 6002105.07 ~S 0.00 0 ',4 0 FROPOSED WELL PROFILE STATION MEASURED INCLN DIRECTION VERTICAL-DEPTHS IDENTIFICATION DEPTH ANGLE AZIMUTH TVD SUB-SEA TKUC1 9265.14 7.68 116.93 7065.90 7005.00 KUPARUK TARGET 9290.36 7.68 116.93 7090.90 70]0.00 TKUB/B8 9315.59 7.68 116.93 7115.90 7055.00 TKB7 9330.72 7.68 116.93 7130.90 7070.00 TKB6 9361.00 7.68 116.93 $160.90 7100.00 TKB5 9381.18 7.68 116.93 TKB4 9416.49 7.68 116.93 TKB3 9446.77 7.68 116.93 TKB2 9471.99 7.68 116.93 TKB1 9512.35 7.68 116.93 9532.54 7.68 116.93 9623.35 7.68 116.93 9810.02 7.68 116.93 10203.55 7.68 116.93 10581.95 7.68 116.93 TXUA TMLV TKNG TJG TJF 10642,49 7,68 11~,93 11010.79 7.68 116.93 11096.56 7.68 116.93 11247.92 7.68 116.93 11318.55 7.68 116.93 TJE/TJD TJC TJB TJA SAG RIVER TARGET 11318.55 7,68 116.93 11394.23 7.68 116.93 11485.05 7.68 116.93 11525.41 7.68 116.93 11525.41 7.68 '116.95 TSGR TSHU TEIL 7" CASING POINT TD SECTI ON DE PART 4811.07 4814.44 4817.81 4819.84 4823.88 COORDINATES- FROM WELLHEAD 3611.37 S 3561.70 3612.89 S 3564.71 3614.42 S 3567.72 3615.33 S 3569.52 3617.17 S 3573.13 ALASKA Zone 4 X Y FACE 100 588103.98 6002101.49 HS 0,00 588109.00 6002100.00 MS 0.00 588110.02 6002098.51 MS 0.00 588111.84 6002097.61 HS 0,00 588115.46 6002095.82 HS 0.00 TOOL 7180.90 7120.00 7215.90 7155.00 7245.90 7185.00 7270.90 7210.00 7310.90 7250.00 7330.90 7270.00 7420.90 7360.00 7605.90 7545.00 7995.90 7935.00' 8370.90 8310.00 8430.90 8370.00 8795.90 8735.00 8880.90 8820.00 9030.90 8970.00 9100.90 9040.00 4826.58 4831.30 4835.34 4838.72 4844.11 4846.81 4859.94 4883.89 4936.48 4987.05 4995.14 5044.36 5055.82 5076.04 5085.48 3618~39 S 3575 3620.53 S 3579 3622,36 S 3583 3623.89 'S 3586 3627.55 S 3'593 3633.05 S 3604 3644.34 S 3626 3668.16 S 3673 3691.06 S 3718 3694.73 S 3717.02 S 3722.21 S 3731.37 S 3735.65 S .53 E .74 E .3~ E .35 E .16 E .56 E .3~ E .51 E .59 E 3725.81 E 376.9.69 E 3779.91 E 3797.94 E 588117.88 6002094.63 ~S 0.00 588122.11 6002092.54 HS 0.00 588125.74 6002090.75 ~S 0.00 188128.76 6002089.25 HS 0~00 588133.60 6002086.87 MS 0.00 588136.01 6002085.67 HS 0.00 588146.90 6002080.30 HS 0.00 588169.26 6002069.25 HS 0.00 588216.41 6002045.97 HS 0.00 588261.75 6002023.58 ~S 0.00 3806.36 E 588350.00 6001980.00 588269.00 6002020.00 HS 0.00 588313.13 6001998,21 HS 0.00 588323.40 6001993.13 HS 0.00 588341.54 6001984.18 HS 0.00 ~S 0.00 9100.90 9040.00 9175.90 9115.00 9265.90 9205.00 9305.90 9245.00 9305.90 9245.00 5085.48 5095.60 5107.73 511].13 5113.13 3735.65 3740.23 3745.72 3748.17 3748.17 3806.36 E 588350.00 6001980.00 HS 0.00 3815.37 E 588359.07 6001975.52 ~S 0.00 3826.19 E 588369.95 6001970.15 ~S 0.00 3831.00 E 588374.78 6001967.76 0.00 3831.00 E 588374.78 6001967.76 0.00 0 0 (Anadrill (c)96 MPK33P4 ].0b.10 11:58 ;tM P) D~C-17-g6 11:24A Anad'~il~--DPC 907 3,~ 2160 P .06 SHARED SERVICES DRILLING I i i i · i MPK-33 (P4) ~[~,~ VERTICAL SECTION VIEW Section at: 116.93 TVD Scale.' 1 inc~ : 1200 feet Dep Scale · ~ inch : 1200 feet <KB> o A ' Drawn ' ~7 Dec 1996 6oo-_ .8..7 l ........... ~-.. II 1 ~ ~nadr~ ]] Schlumberger B._ · ~ ~ Marker Identification ' ~ BKB SECTN '.tNCLN ~200 E Al KB 0 0 0 0.00 I : ' B) KOP/BUILD t/~00 500 500 0 0.00 1800 .... ~~ ' - .... ]--" ........... ~a!'r~sr-~m C) BUILD 1.5/J80- .700 700 . 3 2.00 ...... ~- ..... ............... BI CURVE. 2/100 10~ 999 23 6.50 E) BUILD 2/~00 1~6 ~253 49 6.50 . I ~ ~u~o~.~/~oo- - ~o ,~o~ -~ T 3000 .... , ............. .~ .. ~ .... ' ........ K) END 2.5/100 CURVE 8649 .6466 46/9 ~5.85 LI CURVE 2.5/~00 8852 666~ 4733 ~5.85 V ~' N) END 2.5/t00 CURVE 9190 6992 480S 7.68 . N) KUPARUK TARGET 9290 709~ 4814 7.68 O 3600 O) SAG RIVER ~ARGET 11319 910~ 5085 7.68 PI 7" CASING POINT ~525 9306 5113 7.68 O) fD 1S525 9306 5lt3 7.68 ,,0o .............. 6000 ' ,~oo- r~-~ - - · iiliil iii jiiii iiiiii ..... ........ -:: o 6OO 12OO ~ BO0 2400 3000 3600 4200 4800 5400 6000 6600 '7200 7800 Section Departure (lnadri]l [c)96 MPK3304 3.00.10 12:86 PM P) Ded-17-96 11:25A Anad~il~-DPC 90TM.~ 3,~_2160. P.07 SHARED SERVICES DRILLING Marker Identification MO A) KB 0 B) KOP/8UILD 1/lO0 500 C) BUILD 1.5/~00 700 D) CURVE 2/t00 t000 E) BUILD 2/t00 t256 F) END 2/100 BUILD 1BSO G) BUILD 2.5/~00 ~930 H) END 2.5/~00 BUILD 3369 I) 9-5/8' CASING POINT 6613 J) CURVE 2.5/~00 710~ K) END 2.5/100 CURVE 8649 L) CURVE 2.5/~00 8852 H) END 2.5/100 CURVE 9~90 N) KUPARUK TARGET 9290 OD SAG RIVER TARGET P) 7' CASING POINT N/S E/W ~ ] ON OE ON OE ON 3E ON 26E lO S 50 E ~03 S $38 E ' ~2~ S ~56 E 729 S 735 E 2637 S 2555 .E 2923 S 2829 E 3533 S 3453 E 3568 S. 3496 E 3607 S 3553 E 3613 S 3565 E IvlPK-33 (P4) PLAN VIEW cLOSURE · 5360 feet' at .Azimuth 134.37 DECLINATION' +28.282. (E) SCALE ' ~ inch = 800 feet DRAHN. ' 17 Dec" 1996 .. /nadr 11 Sch]umaerger 1~3~9 3736 S 3806 E ~ 1~525 3748 S '383t E ' L (AnadrJJ] (cj96 NI3K33P4 3.OD.lO J2:08 PN p; 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 <- ~EST ' EAST -> 5200 · WELL PERMIT CHECKLIST COMPANY &POOL ADMINISTRATI~DN ..... 6o 7. 8. 9. 10. 11. 13. Permit fee att=ched ....................... Lease number appropriate .................. Unique we~ name and number ................ Well located in a defined pool ................. Well locaZed proper distance from dflg unit boundary .... Well located proper distance from off, er we~s ........ Sufficient acreage available in drilling unit. ......... If deviated, is wellbore pl~t included ............. Operator only affected party .................. Operator has appropriate bond in force ............ Permit can be issued without conserv~on order ...... Permit can be issued witho~ administrative approval .... Can permit be approved before 15-day wail ........ GEOLmE PROGRAM: exp D dev'~", reddl El serv [] wellbore seg [] ann. disposal para req E] UNIT# '/ ',~..),. ,~. ON~FF SHORE ~,'~ J REMARKS 14. 15. 16. 17. 1R. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided .................. .~N Surface casing protects ail known USDWs .......... _ N OMT vol adequate to circulate on conductor & surf csg . . ..~ N.~ CtvfT vol adequate to tie-in long string to surf csg ..... .~, ~,, CMT will c=ver all known productive horizons ........ Casing designs adequate for C, T, B & Pen'naJmst. .... .fi'~ ~N )N Adequate ta~k~ge or reserve piL .............. ."~ . A-- If a re-drill, has a 10-403 for a,bndnmnt been approved .... '~--N--~v~ Adequate wellbore sepa~don proposed ........... .~ N If diverter required, is it adequate ............... Drilling fiuid progr'~m schen'~tic & equip list adequate .... ~N BOPF_.s adequate .............. ~ .... ....... ~/ N ROPE press ra~ng adequate; test to ~ ~¢~r,Z:~ psig. Y~N Choke mardfold complies w/API RP-53 (May 84) ...... Work will occur wi~out operation shutdown .......... Is presence of H2S gas probable .............. -GEOLOGY .... APPR D,~TE 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N / .. 31. Dat~ presented on potendaJ overpressure zones ....... ,Y, ~ ~"¢.,),.~ 32_ Seismic analysis of shallow gas zones ............. .~.N. 33. Seabed condilJon survey (if off-shore) ........... ./X'Y N 34. Comact name/phone for weekly progress repo~ ,...../.. Y N [e,~loratory onlyJ GEOLOGY: ENGINEERING: COMMISSION: RP~ BEW DWJ JDH ~ JDN ~ v TAB Comments/Instructions: HOW4jb- A.~CORM..,%C-,dd'~ my 4/S6 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Men May 05 16:44:42 1997 Reel Header Service name ............. LISTPE Date ..................... 97/05/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/05/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Corament Record TAPE HEADER MtLNE POINT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-70005 B. ZIEMKE J. PYRON MPK-33 500292272900 BP EXPLORATION (AJ~ASKA), INC. SPERRY-SUN DRILLING SERVICES 05-MAY-97 MWD RUN 2 AK-M~-70005 B. ZIEMKE J. PYRON MWD RUN 3 AK-MM-70005 A. PIEPER J. PYRON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNS HI P: k~_N G E: FNL: FSL: FEL: r ~: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DER?.iCK FLOOR: MWD RUN 4 AK-MM-70005 A. PIEPER J. PYRON 3 12N liE 3536 ~0~6 · 00 61.10 GROUND LEVEL: WELL CASING RECORD !ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 27.50 OPEN HOLE CASING DRILLERS BIT SiZE (iN! SIZE iIN) DEPTH (FT 20.000 112.0 ~.250 -.~5 6666 0 8.500 11543.0 !. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GA20~A RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 4. MWD RUNS 3 AND 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP) AND STABILIZED LITHO DENSITY (SLD). 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11543' MD, 9310' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA -SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SBDC = SMOOTHED BULK DENSITY (CALIPER CORRECTED). SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR/NEUTRON LOG PROCESSING: HOLE SIZE = ..MUD FILTRATE SALINITY = P~D WEIGHT = FORM_ATiON WATER SALINITY = FLUID DENSITY = ~TRIX DENSITY = LiTHOLOGY = $ File Header Service name ............. STSLiB.00! Service Sub Level Name... ver~om 0 0 Date of Generation ....... 9U/05/05 Maximum Ph';sica~ Reccrd..65535 . _ze T~z'pe ................ LO Previous File Name ....... STSLIB.000 750-800 PPM 8.5 - 11.2 PPG 14545 PPM 1.0 G/CC 2.65 G/CC S.~NDSTONE Comment Reccrd FiLE H~DER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FiLE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP DRHO RHOB FCNT NCNT NPHI PEF $ START DEPTH 238.5 248.0 248.0 248.0 248.0 248 0 302 0 6656 0 6656 0 6656 0 6656 0 6656.0 6659.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 238.5 6594.0 6650.5 6694.5 6711.5 6718 5 6723 5 6766 5 6785 5 6794 0 6818 5 6825.0 6833.0 6845.0 6882.0 6900.5 6906 0 6950 0 6952 0 6988 5 6992 5 6994 0 6999 5 7008 5 7012 0 7096 5 7125 5 7140 0 7445 5 7452 5 7~72 $ 7829 5 78~ 7873 5 ~880 5 °46a 0 GR 255.0 6610.5 6656.5 6705.5 6724.5 6732.5 6737.0 6776.0 6800.0 6806.0 6828.5 6835.0 6846.0 6859.5 6888.0 6904.5 6909.0 6956.5 6959.5 6988 5 6993 0 6995 5 7016 5 7023 0 7028 0 7114 5 7137 5 7148 0 7461 5 7471 5 7787 5 7846 0 7884 5 7889 0 7898.0 8478.5 STOP DEPTH 11476 5 11449 5 11449 5 11449 5 11449 5 11449 5 11535 5 11465.5 11465.5 11457.5 11457.5 11457.5 11466.0 EQUIVALENT UNSHIFTED DEPTH ......... 8472 5 8480 5 8485 0 8488 5 8501 0 8515 0 8531 5 8534 5 8537 5 8539 0 8540 0 8543 5 8546 0 8547 5 8551 0 8552.5 8557.0 8558.5 8562.0 8568 5 8587 5 8593 5 8601 0 8607 0 8611 0 8623 5 8628.5 8632.0 8634.0 8637.5 8643.0 8648.0 8654.5 8658.0 8660.5 8662.5 8666.5 8670.0 8673.5 8675.5 8677.5 8682.5 8685 5 8690 0 8696 0 8703 5 8708 5 8709 5 8714 0 8717 5 8726 5 8728 5 8732 0 8734.5 8739.0 8744 5 8747 5 8~r-.4 8758 5 8763 5 8768 iD 8780 5 ~,84 0 8789 0 c485 5 8497 0 8500 5 8503 5 8515 5 8530 0 8544 0 8545 0 8548 0 8549 5 8552 0 8556 0 8559.5 8562.5 8565.5 8566.5 8569.5 8572.0 8575.0 8580.5 8598.5 8602.5 8614.5 8620.5 8624.0 8633.5 8641.0 8644.5 8647.5 8652.5 8656.0 8660.5 8667.0 8671.5 8674.0 8675.0 8680.0 8684.0 8686.0 8688.0 8691.0 8695.5 8698.5 8702.5 8706.5 8713.5 8719 0 8721 5 8726 5 8730 0 8739 5 8741 5 8744 0 8747 5 8751 5 8756 0 8757 0 8763 ~ 87~0 0 8775 5 ~78~ 5 8792 5 8796 5 8799 5 8793 0 8801 0 8806 5 8812 5 8824 5 8830 0 8836 0 8841 0 8845 5 8848 0 8850 0 8851 0 8851 5 8852 0 8855 0 8855 5 8857 5 8858 5 8860 5 8862 5 8865 0 8868 5 8871 0 8876 0 8881 5 8886 5 8888.0 8890.0 8895.5 8896.5 8898.5 8901.0 8902.5 8907.5 8909.0 8922.0 8935.5 8937.5 8945.0 8952.5 8971.5 8973.0 8974.5 8977.0 8979.0 8980.5 8987 0 8990 0 8993 5 8999 5 9000 5 9002 0 9015 0 9017 0 9018 5 9043 5 9045 5 ,J56~ ~ 9057 5 9083 5 9085 5 9087 0 9098 0 9100 0 8803 5 8812 0 8818 0 8822 5 8830 0 8841 5 8847 5 8853 5 8857 5 8859 5 886O 5 8861.5 8862.0 8862.5 8866.5 8868.0 8870.0 8872.0 8873.0 8875.5 8878.5 8884.0 8889.0 8893.0 8894.5 8896.0 8897.0 8900.0 8904.5 8907.5 8909.0 8914.0 8915.5 8920.5 8921.0 8936.5 8946.5 8948.0 8958.0 8964.5 8980.0 8981.0 8986.5 8989.0 8993.0 8994.5 8996 0 9001 5 9004 0 9011 0 9012 5 9014 5 9027 5 9029 0 9030 5 9055 0 9057 0 9065 0 9066 0 9095 0 909~ 5 9098 5 9111 0 9114 0 9102. 0 9103.0 9105-.0 9107.5 9110.5 9117 0 9119 0 9125 5 9127 0 9201 0 9210 5 9215 0 9219 0 9221 5 9224 0 9237 0 9242 0 9265 0 9266 5 9268.5 9279.5 9281.0 9290.0 9292.0 9299.5 9303.0 9304.5 9306 5 9309 0 9312 5 9315 0 9318 0 9320 0 9325 0 9330 5 9332 0 9334 5 9339 0 9343 5 9346 0 9408 0 9409 5 9432 5 9434 0 9437.0 9441.5 9447.5 9451.0 9453 0 9456 0 9459 0 9466 0 9475 0 9506 5 9522 0 9524 0 9529 5 9532 0 9534 5 9537 0 9541 5 9545 0 9547 0 9634 0 ~1!5 5 9119 0 9121 5 °!?~ 5 9124 0 9132 0 9133 5 9138 0 9139 0 9218 0 9223 5 9229 0 9232 0 9234 5 9237 5 9249.5 9253.5 9277.0 9277.5 9279.0 9292.0 9293.0 9301.0 9304 0 9311 0 9314 0 9316 0 9318 0 9321 0 9324 5 9328 0 9329 5 9331 0 9334 5 9341 5 9344 5 9347 0 9351 5 9355.5 9358.0 9420.0 9421.5 9443.0 9446.0 9449.0 9454.0 9456.5 9462.0 9465.0 9467.5 9470.5 9478.0 9487.5 9518.0 9531 5 9535 5 9541 0 9543 5 9546 0 9548 5 9553 0 9557 0 ~=~q 0 9644 5 9636 9637 · 9671 9673 9745 9747 9780 9782 10175 10178 10182 10191 10197 10201 10204 10207 10210 10215 10217 10221 10223 10315 10317 10319 10322 10326 10327 10330 10360 10365 10406 10410 10412 10491 10494 10498 10537 10539 10623 10635 10646 10662 10675 10680 10688 10728 10746 10779 10799 10825 10831 10834 10838 10842 10848 10850 10853 11120 11122 i~67 11169 0 5 5 5 0 0 5 0 0 5 5 5 5 5 5 0 0 0 5 0 0 .5 .5 .5 .0 .0 .5 .5 .5 .0 .0 0 0 5 0 0 5 5 5 0 0 0 5 0 0 0 0 0 0 0 0 5 5 .5 0 5 5 0 0 0 0 5 0 0 ~646 5 9649 0 9683 5 9686 0 9760 5 9761 5 9796 0 9797 0 10185 0 10188 5 10193 0 10201 5 10207 5 10210 0 10214 5 10217 5 10221 0 10224 5 10228 5 10232 0 10233 5 10328 5 10329 5 10331 5 10334.0 10337.5 10340.5 10343.0 10373.5 10376.5 10413.5 10417.0 10419.0 10502.5 10505.5 10506.5 10550.0 10552.0 10636.5 10646.5 10657.5 10675.0 10689 5 10694 0 10698 5 10743 0 10759 5 10785 0 10810 0 10834 5 10840 0 10844 0 10849 5 10853 0 10858 0 10861 0 10863 5 11129 5 11132 0 11134 0 11168 0 11173 5 11176 5 11177 5 11170 11198 11256 11260 11262 11322 11348 11359 11361 11363 11366 11369 11371 11374 11403 11406 11408 11409 11412 11415 11418 11421 11425 11431 11439. 11441. 11449. 11535. $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: ~z179 11200 11264 11268 11271 11335 11356 11366 11369 11371 11380 11381 11382 11385 11415 11418 11419 11420 11423. 11427. 11428. 11433. 11436. 11440. 11449. 11450. 11456. 11543. BIT RUN NO MERGE TOP MERGE BASE 1 318.0 4846.0 2 4846.0 6686.0 3 6686.0 11433.0 4 11433.0 11543.0 MERGED ~IN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT GR ROP RPX RPS RPH RPD FET NPHi FCNT Service Order Units FT 4 ! 68 P~D AAPI 4 1 68 P~D FT/H 4 ! 68 P~D OHNM. 4 ! 68 .~N~ ~ OH~ . '~i 6 8 P~D OHN~ 4 1 68 ~D OHHM 4 ! 68 P~D HOUR 4 ! 68 NNgD P.U. 4 i 68 P~D CNTS 4 t 68 Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 32 9 36 !0 NCNT RHOB DRHO MWD PEF .~WD u~TS 4 1 68 G/CC 4 i 68 G/CC 4 1 68 BARN 4 1 68 4O 44 48 52 I1 12 13 14 Name DEPT GR ROP RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Min 238.5 i0 7154 5 4788 0 0854 0 0629 0 0643 0 0703 0 1097 7 1584 406.93 2082.04 1.5782 -0.249 1. 7323 Max Mean Nsam 11535.5 5887 22595 340.925 72.6926 22477 775.571 177.885 22468 2000 7.09683 22404 2000 8.95624 22404 2000 12.5153 22404 2000 21.1102 22404 74.9152 1.82333 22404 81.7622 50.65 9604 1834.08 552.8 9604 4584.49 2611.82 9604 3.4293 2.40595 9620 0.6345 0.0239341 9620 17.3228 2.60278 9615 First Reading 238.5 238.5 302 248 248 248 248 248 6656 6656 6656 6656 6656 6659 Last Reading 11535.5 11476.5 11535.5 11449.5 11449.5 11449.5 11449.5 11449.5 11457.5 11457.5 11457.5 11465.5 11465.5 11466 First Reading For Entire File .......... 238.5 Last Reading For Entire File ........... 11535.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/05 Maximum Physical Record..65535 FJ!e Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Co~ent Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and icg header data for each bit run in separate files. BiT RUN NUMBER: 1 DEPTH iNCREMENT: .5000 FiLE SU~RY VENDOR TOOL CODE START DEPTH ,SR 255.0 ==~ 264 5 RPD 264.5 STOP DEPTH 4782.0 4792.0 4792.0 RPM 264.5 RPS 264.5 RPX 264.5 ROP 318.5 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE {MEMORY OR REAL-TiME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM .ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE .AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4792.0 4792.0 4792.0 4845.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OH~94) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA~[DOFF (IN): EWR FREQUENCY (HZ): RE~ARKS: $ Data Format Specification Record Data Record ~e .................. 0 Data Sueclfication Block Type ..... 0 Loo~inc ~ c~ion Down ._~e ................. Op~i.-=~ ~ de~th units Fe~t Data Re~ ...... Point .............. Undefined Frame S~acing ..................... 60 .lin Max frames eer record ............. Undefined A~sen~ va~,,= , _aaa ~e~ u~l~s ....................... !!-JAN-97 4.88 CIM 5.46 MEMORY 4846.0 318.0 4846.0 .4 58.4 TOOL NUMBER P0628CGR8 P0628CGR8 12.250 12.3 SPUD 10.20 95.0 8.6 600 10.0 2.900 2.570 2.300 3.300 37.8 Datum Specificatio.~ Block sub-ti?pe...0 DEPT GR RPX RPS RPM RPD ROP FET Name Service Order Units Size Nsam FT 4 ! MWD ! ~'AP I 4 ! !~/~ D '~ O H MM 4 ~ WWD ! OHM~ 4 1 .u%. ~D i OHM~ 4 ! MWD I OHMM 4 ! MWD ! FT/H 4 1 I~D 1 HOUR 4 1 ~s Channel Rep Code O=~ et 68 0 ! 68 4 _ 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 255 4845.5 2550.25 GR 10.7154 100.421 54.2066 RPX 0.0854 111.604 12.5245 RPS 0.0629 223.158 16.9458 RPM 0.0643 2000 26.2677 RPD 0.0703 2000 28.7 ROP 11.0591 775.571 207.701 FET 0.1097 5.1352 0.690949 First Last Nsam Reading Reading 9182 255 4845.5 9055 255 4782 9056 264.5 4792 9056 264.5 4792 9056 264.5 4792 9056 264.5 4792 9055 318.5 4845.5 9056 264.5 4792 First Reading For Entire File .......... 255 Last Reading For Entire File ........... 4845.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation~ ...... 97/05/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE H~ADER FILE NUMBER: 3 P~W P~D Curves and icg header dana for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH iNCREMENT: .5000 Fi LE SU~RY VENDOR TOOL CODE START DE~H GR 4772.0 FET 4781.0 STOP DEPTH 6610.0 6620.0 RPD ~78!. 0 RPM 4781.0 RPS 4781.0 RPX 4781.0 ROP 4847.5 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER {FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) '. BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG . $ BOREHOLE .AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6620.0 6620.0 6620.0 6620.0 6686.0 RESIS. 4 BOREHOLE CONDITIONS MUD TYPE :- MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT PLAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: NEJD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (iN): EWR FREQUENCY (HZ): REMARKS: ^ Data Format Specification Record Data Record T'.-De .................. 0 __ Data Specifi:anion Block Type ..... 0 Lcgging Dire::icn ................. Dcwn ~~ ~-~,~ ~=~h u~i~s ~ee~ Data Reference Point .............. Undefined Frame Suacing.. ~ .................. 60 .liN Max frames pe~ record ............. Undefined A~sent value ...................... -999.25 13-JAN-97 4.88 CIM 5.46 MEMORY 6686.0 4846.0 6686.0 51.5 58.5 TOOL NUMBER P0628CGR8 P0628CGR8 12.250 12.3 SPUD 10.20 79.0 8.5 1000 6.0 2.9 2.4 2.3 3.3 00 37 41.1 00 00 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 ! 68 0 I GR b~D 2 AAPi 4 1 68 4 2 RPX ~D 2 OHM}4 4 1 68 8 3 RPS ~D 2 OHM}4 4 i 68 12 4 RPM ~D~ ~ OHI<M ~. l_ 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 ROP MWD 2 FT/H 4 ! 68 24 7 FET MWD 2 HOUR 4 ! 68 28 8 First Name Min Max Mean Nsam Reading DEPT 4772 6686 5729 3829 4772 GR 17.9104 100.319 55.1887 3677 4772 RPX 0.9807 20.6312 3.89323 3679 4781 RPS 0.9575 23.459 4.20533 3679 4781 RPM 0.9625 23.8924 4.29624 3679 4781 RPD 0.9812 24.1161 4.466 3679 4781 ROP 6.716 553.693 162.18 3678 4847.5 FET 0.2642 13.2989 1.38236 3679 4781 Last Reading 6686 6610 6620 6620 6620 6620 6686 6620 First Reading For Entire File .......... 4772 Last Reading For Entire File ........... 6686 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/05 Maximum Phvsica! Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record Fi LE HEADER FILE NUMBER: 4 RAW P5gD Curves and icg header data for each bit run in separate files. BiT RUN NUMBE.~.: 3 DEPTH iNCREMENT: .5000 FiLE S UP~L'~.RY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 6581.0 11346.0 RPD RPM RPS RPX GR DRHO RHOB FCNT NCNT NPHI PEF ROP $ LOG HEADER DATA DATE LOGGED: S O FTWARE o581 0 6581 0 6581 0 6581 0 6609 5 6663 0 6663 0 6663 0 6663 0 6663 0 6666 0 6667 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 11346.0 11346.0 11346.0 11346.0 11373.5 11362 5 11362 5 11354 5 11354 5 11354 5 11363 0 11432 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAM~A RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABI. LITHO DENSITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHM}4) AT TEMPERATURE {DEGF) MUD AT MEASURED TEMPERATURE (MT): MLTD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL ~£'AT RI X: PtATRIX DENSITY: HOLE '~"" '~mT ~ ~RR~_ON .,IN): RENL'-.RK S: 19-JAN-97 4.88 CIM 5.46 MEMORY 11433.0 6686.0 11433.0 7.1 52.2 TOOL NUMBER P0619CRNDG6 P0619CRNDG6 P0619CRNDG6 P0619CRNDG6 8.500 8.5 LSND 11.20 44.0 8.8 750 120.0 2.400 1.060 2.300 3.100 77.8 Data Forma~ Specificauion Record Data Reccrd Type .................. 0 Data Specification Block Type ..... 0 Logging DirecTion ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max = =tames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 3 AAPI 4 1 RPX MWD 3 OHMH 4 1 RPS MWD 3 OHMM 4 1 RPM MWD 3 OHMM 4 1 RPD MWD 3 OHM~ 4 1 NPHI MWD 3 P.U. 4 1 . ROP MWD 3 FT/H 4 1 FET MWD 3 HOUR 4 1 FCNT MWD 3 CNTS 4 1 NCNT MWD 3 CNTS 4 1 RHOB MWD 3 G/CC 4 1 DRHO MWD 3 G/CC 4 1 PEF MWD 3 BARN 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name DEPT GR RPX RPS RPM RPD NPHI ROP FET FCNT NCNT RHOB DRHO PEF Min 6581 26 3295 0 5772 0 4574 0 2997 0 2764 17 1251 6 2423 0 2359 406.93 2082.04 1.5782 -0.249 1.7323 First Max Mean Nsam Reading 11432 9006.5 9703 6581 292.681 96.9832 9529 6609.5 2000 3.22653 9531 6581 2000 3.32223 9531 6581 2000 3.14072 9531 6581 2000 32.2588 9531 6581 81.7622 51.2298 9384 6663 655.905 160.452 9530 6667.5 74.9322 3.20909 9531 6581 867 546.29 9384 6663 3704 2596.95 9384 6663 3.4293 2.40373 9400 6663 0.6345 0.0244363 9400 6663 17.3228 2.59982 9395 6666 Last Reading 11432 11373.5 11346 11346 11346 11346 11354.5 11432 11346 11354.5 11354.5 11362.5 11362.5 11363 First Reading For Entire File .......... 6581 Last Reading For Entire File ........... 11432 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date cf Generation ....... 97/05/05 Maximum Phvsica! Record..65535 - File Type ................ LO Next File Name ........... STSLIB.005 Phvsica! EOF - File Header Service name ............. STSLIB,005 _~_c~ Sub Level Name,,. Version Number ........... 1,0,0 Date cf Generation ....... 97/05/05 Maximum ~hv=ical Record 6~535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HE~XDER FiLE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files, BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 11347,0 RPD 11347,0 RPM 11347,0 RPS 11347,0 RPX 11347,0 FCNT 11355,5 NCNT 11355,5 NPHI 11355,5 PEF 11364,0 DRHO 11364,0 RHOB 11364,0 GR 11374,5 ROP 11434,5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM A/qGLE: TOOL STRING (TOP TO BOTTOM) VENDOR ~ n- ;O~m CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 11457 0 11457 0 11457 0 11457 0 11457 0 11465 0 11465 0 11465 0 11473 5 11473 0 11473 0 11484 0 11543 0 21-JAN-97 4.88 CIM 5,46 MEMORY 11543,0 11433,0 11543,0 7,5 7,5 TOOL NUMBER P0619CRNDG6 EWR4 CNP SLD $ ELECTROMAG, RESIS, 4 COMPENSATED NEUTRON STABI, LITHO DENSITY BOREHOLE A~[D CASING DATA C-PEN H,~;r~ =tm ~iZE (IN): DRILLER'S CASING DEPTH (FT) : BOPEWOT.E ~D DENSITY :LB/G) : P0619CRNDG6 P0619CRNDG6 P0619CRNDG6 8.500 8.5 LSND 11,20 · ~FgD ViSCOSiTY (a} : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESiSTIViTY (OH.MM) AT TEMPERATURE (DEGF) i~.JD AT M~ASURED TEMPE.~TURE (MT): MUD AT Ptzl{ CIRCULATING TERMPERATURE: k~D FILTRATE AT MT: .~fgD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 45.0 8.7 750 4.2 2.400 .980 2.300 3.100 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 RPX MWD 4 OHMM 4 1 68 8 3 RPS MWD 4 OHMM 4 1 68 12 4 RPM MWD 4 OHMM 4 1 68 16 5 RPD MWD 4 OHM}{ 4 1 68 20 6 NPHI MWD 4 P.U. ~ 1 68 24 7 ROP MWD 4 FT/H 4 1 68 28 8 FET MWD 4 HOUR 4 1 68 32 9 FCNT MWD 4 CNTS 4 1 68 36 10 NCNT MWD 4 CNTS 4 1 68 40 11 RHOB MWD 4 G/CC 4 1 68 44 12 DRHO MWD 4 G/CC 4 1 68 48 13 PEF MWD 4 BARN 4 1 68 52 14 85.5 N a me DEPT GR RPX RPS RPH RPD NPHi RCP FET FONT NCNT · '?.i n 11347 39 2511 ! 1508 I ~ ! 3-P47 i 1336 6 123,8 40- 2228.94 Max 11543 340.925 90 0962 69 1046 67 6168 68 1312 71 9287 95 3445 24 3144 i$34.0~ 4584.49 Mean Nsam 11445 79 5313 13 3513 12 8146 12 0408 12 5121 2® ~58 24 7761 19 4201 813.177 3186.61 First Last Reading Reading 393 11347 11543 220 11374.5 11484 221 11347 11457 221 11347 11457 221 11347 11457 221 11347 11457 ~20 11355 5 11465 ~ · 218 11434.5 11543 221 11347 11457 220 11355.5 11465 =~0 11355.5 11465 RHOB 2.3036 2.7086 2.47871 DRHO -0.0!i 0.0364 0.010142 PEF 2.2694 5.0512 2.85297 219 11364 11473 219 11364 11473 220 11364 11473.5 First Reading For Entire File .......... 11347 Last Reading For Entire File ........... 11543 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LiSTPE Date ..................... 97/05/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 97/05/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LiS File · 2o% * ALASKA COMPUTING CENTER . ****************************** * ............................ * ....... SCHLUMBERGER ....... * ............................ ****************************** COMPANY NAME : BP EXPLORATION (ALASKA) WELL NAME : MP K- 33 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22729-00 REFEREa~CE NO : 97150 Date~ LIS T'ape V~:fication Listing Schlumberger Alaska Computing Center 15-APR-1997 11:33 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 97/04/15 ORIGIN : FLIC REEL NAME : 97150 CONTINUATION # : PREVIOUS REEL : COf4~ENT . BP EXPLORATION (ALASKA), MILNE POINT, MPK-33, API #50-029-22729- **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/04/15 ORIGIN : FLIC TAPE NAME : 97150 CONTINUATION # : 1 PREVIOUS TAPE : COfZk~_~NT : BP EXPLORATION (ALASKA), MILNE POINT, MPK-33, API #50-029-22729- TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NAME: MP K-33 API NUMBER: 500292272900 OPERATOR: BP EXPLORATION (ALASKA) LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 13-APR-97 JOB NUMBER: 97150 LOGGING ENGINEER: YON OPERATOR WITNESS: HINKEL SURFACE LOCATION SECTION: 3 TOWNSHIP .. 12N RANGE: liE FNL: FSL: 353 6 FEL: 2056 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 60.80 DERRICK FLOOR: 60.80 GROUND LEVEL: 27.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS ~ape V~fication Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: NONE LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ REMARKS: 15-APR-1997 11:33 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH ....... THIS FILE CONTAINS THE LDWG EDIT FOR THE GR/CCL DEPTH CONTROL LOG FOR BP EXPLORATION WELL MPK-33 WELL. THIS IS THE PDC GANk4A RAY RUN USING MAGNETIC MARKS ON 1-29- 97 BY SWS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION ' O01CO1 DATE : 97/04/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~ff4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11456.0 6518.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH $ REMARKS: THIS FILE CONTAINS THE EDITED MAIN PASS GRCH. THE LIS ~ape Verification Listing Schlumberger Alaska Computing Center 15-APR-1997 11:33 PAGE: CURVES WERE CLIPPED AND NO DEPTH SHIFTING WAS PERFORMED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553881 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GR GAPI 553881 O0 000 O0 0 1 1 1 4 68 0000000000 TENS GR LB 553881 O0 000 O0 0 1 1 1 4 68 0000000000 CCL GR V 553881 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11456.000 GRCH. GR 58.895 TENS.GR 3576.000 CCL.GR DEPT. 6518.000 GRCH. GR 29.500 TENS.GR 1848.000 CCL.GR -0. 002 -0. 003 ** END OF DATA ** LIS T'ape Ve~=fication Listing Schlumberger Alaska Computing Center 15-APR-1997 11:33 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 97/04/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11488.0 6517.5 GRCH $ LOG H~ER DATA DATE LOGGED: 29-JAN-97 SOFTWARE VERSION: 8B0-538 TIME LOGGER ON BOTTOM: 159 30-JAN-97 TD DRILLER (FT) : 11483.0 TD LOGGER (FT) : 11454.0 TOP LOG INTERVAL (FT) : 6520.0 BOTTOM LOG INTERVAL (FT) '. 11449.0 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GRCH COLLAR LOCATOR CAL- Y GRCH TELEMETRY CARTRIDGE TCC- B GRCH GAlV~IA RAY SGT- L GRCH GA~VA RAY BNS-CCS $ L'IS T~pe Vel~ication Listing Schlumberger Alaska Computing Center 15-APR-1997 11:33 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 8.500 0.0 11483.0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS) : NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: *********** RUN NUMBER 1 THE GR/CCL LOG IS THE PRIMARY DEPTH LOG. IT WAS RUN USING MAGNETIC MARKS ON 1-29-97 BY SWS THE TOOL WAS ZEROED AT PAD LEVEL = 27.8 GL HENCE THE ZERO DEPTH WAS 33 FT AT PAD LEVEL WHEN REFERENCED TO DF ELEV. = 60.8 FT. RIG THAT DRILLED WAS NABORS 27E. $ LIS FORMAT DATA LIS ~ape Ve~.=fication Listing Schlumberger Alaska Computing Center 15-APR-1997 11:33 PAGE: 6 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553881 O0 000 O0 0 2 1 1 4 68 0000000000 GR LOG GAPI 553881 O0 000 O0 0 2 1 1 4 68 0000000000 TENS LOG LB 553881 O0 000 O0 0 2 1 1 4 68 0000000000 CCL LOG V 553881 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11488.000 GR.LOG DEPT. 6517.500 GR.LOG 60.935 TENS.LOG 1908.000 CCL.LOG -0.002 29.500 TENS.LOG 1821.000 CCL.LOG -999.250 ** END OF DATA ** ~IS ~ Tape Vez=£ication Listing Schlumberger Alaska Computing Center 15-APR-1997 11:33 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION ' O01CO1 DATE ' 97/04/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 97/04/15 ORIGIN : FLIC TAPE NAME : 97150 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION (ALASKA), MILNE POINT, MPK-33, API #50-029-22729- **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/04/15 ORIGIN · FLIC REEL NAME : 97150 CONTINUATION # : PREVIOUS REEL : COfZ~fENT : BP EXPLORATION (ALASKA), MILNE POINT, MPK-33, API #50-029-22729-
